presentation by jarrod luze of dgr engineering regarding ......jul 24, 2018 · crews have started...

AGENDA

PUBLIC UTILITIES COMMISSION MEETING

New Ulm, Minnesota

CITY HALL COUNCIL CHAMBERS

Tuesday, July 24, 2018 — 4: 30 p.m.

1. APPROVE THE MINUTES of the Regular Meeting held June 26, 2018.

2. RECEIVE FROM OFFICERS, BOARDS AND COMMISSIONS:

a. Report regarding Utility operations during the month of July 2018.

b. Presentation by Jarrod Luze of DGR Engineering regarding New Ulm' s ElectricSystem Study and 20 Year Capital Improvements Plan.

3. NEW BUSINESS:

a. Consider authorizing the City Manager to accept and sign the proposal fromDGR Engineering for the development of a feasibility study of options to rebuildthe east side transmission line.

b. Consider approving the New Ulm High School Energy Education and ResearchGrant application.

C. Consider the purchase of ESET Antivirus three-year renewal.

d. Consider the renewal of email filtering service and support subscription.

e. Consider the purchase of a three-year license for computer management

software.

4. CLAIMS AND ESTIMATES:

a. Consider acceptance of List of Claims Paid and approval of List of Claims to Be

Paid.

5. COMMISSIONER COMMENTS:

City of New UlmRequest for Public Utilities Commission Action

Meeting Date: July 24, 2018 Agenda Item Number: 1.

Agenda Section: Approve the Minutes Originating Department: Finance

Resolution: N/A Prepared By: Nicole Jorgensen

Number of Attachments: One Presented By: Nicole Jorgensen

Item: Consider approving the minutes of the Regular Meeting held June 26, 2018.

Director' s Proposed Action:

Motion by , second by26, 2018.

Board/Commission Recommendation:

Overview:

Primary Issues/ Alternatives to Consider:

Budgetary/Fiscal Issues:

Attachments:

Minutes from the June 26, 2018 Regular Meeting

to approve the minutes of the Regular Meeting held June

PUBLIC UTILITIES COMMISSION

JUNE 26, 2018 — 4: 30 P. M.

The REGULAR MEETING of the Public Utilities Commission of the City of New Ulm, Brown County, Minnesota was duly called and held in the City Hall Council Chambers, on the261h

day of June 2018 at 4: 30 p.m. Present at said meeting was Commissioners Fingland, Hillesheim, Schanus, Swan and President Heine. Also present at said meeting were CityManager Gramentz, Assistant City Attorney Borgen, Finance Director Jorgensen and UtilityEngineer Pirsig.

Commissioner Fingland moved to approve the minutes from the Regular Public Utilities

Commission Meeting held on May 22, 2018 with corrections. The motion was duly seconded byCommissioner Swan and passed by the unanimous vote of all members.

Commissioner Fingland moved to approve the minutes from the Special Public Utilities

Commission Meeting held on June 18, 2018. The motion was duly seconded by CommissionerSwan and passed by the unanimous vote of all members.

Commissioner Swan moved to receive and order filed the report regarding utilityoperations during the month of June 2018. City Manager Gramentz highlighted the mostsignificant events included in the utility department reports. He explained that the Utilities

Director that was previously appointed has declined employment and explained how the processwill work going forward. President Heine recognized the following individual as " Employee ofthe Month":

Patrick Kukla, Mechanic Welder Gas Department

The motion was duly seconded by Commissioner Hillesheim and passed by the unanimous voteof all members.

Finance Director Jorgensen presented the comprehensive annual financial report for the

New Ulm Public Utilities Commission for the fiscal year ended December 31, 2017.

Commissioner Hillesheim moved to receive the comprehensive annual financial report for the

New Ulm Public Utilities Commission for the fiscal year ended December 31, 2017. The motion

was duly seconded by Commissioner Schanus and passed by unanimous vote of all members.

City Manager Gramentz summarized the purchase of Windows Server licensing. Commissioner Fingland moved to authorize the purchase of Windows Server 2016 Datacenter

and user client access licenses ( CALs) from SHI International Corp. in the amount of $20, 816. The motion was duly seconded by Commissioner Hillesheim and passed by unanimous vote ofall members.

Commissioner Hillesheim moved to declare Electric Production water softeners and other

equipment as surplus property and authorize disposition pursuant to the requirements of the City

PUBLIC UTILITIES COMMISSION - REGULAR MEETING 19 JUNE 26, 2018

Code and Charter. The motion was duly seconded by Commissioner Fingland and passed byunanimous vote of all members.

Commissioner Schanus moved to declare an electric Distribution Department vehicle as

surplus property and authorize disposition pursuant to the requirements of the City Code andCharter. The motion was duly seconded by Commissioner Swan and passed by unanimous voteof all members.

Commissioner Fingland moved to receive the REPORT OF CLAIMS PAID in the amount of

2, 707, 039. 17 and to receive and order paid the REPORT OF CLAIMS TO BE PAID in the amount of

626,025. 09 as presented by President Heine. The motion was duly seconded by CommissionerHillesheim and passed by the unanimous vote of all members.

The Commission thereupon adjourned at 4: 42 p.m.

Approved July 24, 2018

Nicole L. Jorgensen

Secretary -Public Utilities Commission

Linda Heine, President

Public Utilities Commission

PUBLIC UTILITIES COMMISSION - REGULAR MEETING 20 JUNE 26, 2018


Meeting Date: July 24, 2018 Agenda Item Number: 2. a.

Agenda Section: Receive from Officers,

Boards and Commissions Originating Department: PUC Administration

Resolution: N/A Prepared By: PUC Staff

Number of Attachments: One Presented By: Dan Pirsig

Item: Report regarding Utility operations during the month of July 2018.


Motion by , second byoperations during the month of July 2018.

Board/ Commission Recommendation:

Overview:

to receive and order filed the report regarding Utility

Employee of the Month: Aaron Duchene, Water/Steam Operator, Water/Steam Department. Aaron has been employed byPublic Utilities since September 2014. He recently volunteered to assist at the Material Distribution Center, and MDCstaff stated that Aaron' s quick offer to help was of great benefit to them. He is a member of the Safety Committee andregularly performs his job above expectations.



Attachments:

Monthly operations and investment summary

TO: Public Utilities Commission

FROM: City Manager

DATE: July 24, 2018

RE: Director's Report for July 24, 2018

Electric Distribution

Electric system experienced one ( 1) breaker operation, 331 WC1. Problem was

found and fixed. The crews also responded to four (4) trouble calls this month.

The department has received and located 253 Gopher State One Call tickets for the

months of June/July. To date the department has processed 45 service applications for the installation of

new and/ or overhead to underground electric conversions.

Crews worked 316 hours on underground maintenance and capital projects.

Crews worked 12 hours on overhead maintenance projects.

Crews worked 21 hours on street lighting maintenance projects. Crews worked 31 hours on maintenance of tools and equipment for the 2018

construction season.

Crews worked 45.5 hours on the changeover from HPS street light fixtures to LED

fixtures.

Crews have started to install underground services.

Crews have started to replace bad Distribution poles (Osmose inspected).

We have started to work on an underground project at St. Paul' s School. We need to

move the location of the transformer and upgrade the service.

A crew is working on feeder 433W to complete the final part of overhead tounderground on the hill from Oakwood to Sunset avenues.

Electric Production

Purchased a used station power controller ( SPC) from Turbo Services and installedinto # 7 Gas Turbine. It still had load swings. Electric technicians found a phase

shifting transformer that was bad, replaced it and it now works great. Shut down back pressure turbine and started # 6 Elliott for summer run. The # 2

cooling tower is on. Completed URGE test of #6 Elliott.

MPCA and GADS reports completed.

Annual maintenance completed on Back Pressure Turbines.

Had sulfuric acid line suffer a failure, isolated tank and line was drained. Notified

Minnesota duty officer of spill. Had Braun Intertec supervise clean up. Replaced line. 6 Elliott tripped out due to breaker operation of 331WC1. Lost boiler also. Got boiler

restarted and generator back on line.

Elliott off line and cooling tower drained. Updated software and licensing for #7 Gas Turbine. Cleaned cooling tower #3, preparing for #4 generator start up. Found variable frequency drive ( VFD) on # 3 cooling tower failed, ordered new oneand installed.

Monthly preventive maintenance completed. The peak load for the month of June was 43, 113 megawatts, occurring on June 29. Process steam and district energy load was 6, 944 Mlbs. for the month.

1

Purchase power of 19, 372. 04 megawatt hours and generation of 264.689 MWh.

The # 2 boiler is on line using natural gas providing steam to process and DistrictEnergy customers. The # 1 boiler is in hot standby, and the monthly test runs of thegas turbines has been completed.

Gas

Gas Supervisor attended the Prairieland Utility Coordinating Committee ( PUCC)

meeting held in Austin, Minnesota, on June 20, 2018. Gas Supervisor completed the following reports: Minnesota Department of

Commerce Annual Natural Gas Utility Report, bimonthly Minnesota Office of PipelineSafety (MNOPS) Emergency response report, and quarterly MNOPS damage report.

During the period: o Received System Analysis final report from Lake Superior Consulting. o Staff are busy locating as Gopher State One Call tickets have increased. o Informed the cities of Tyler, Morgan and Fairfax of phone number changes for

emergency purposes. o Received new laser remote gas leak detector from Groebner & Associates.

o Installed a meter set for St. Paul' s School.

o Relocated and installed an anode on 2nd North Street between Washington and

Franklin streets and at 6th North and German Street.

o Installed test station and anodes at insulated flange location on Bridge Street.

o Recoated and painted service risers that were found with atmospheric corrosion

during our annual residential leak survey. o Installed four new gas services.

o Installed three new gas services for the City of Fairfax. o Annual main leak survey continues. o Cut and capped service for 1729 Oakwood Avenue due to demolition of existing

buildings.

o Checked Fairfax meter and mercury instrument due to zero consumption. o Welder assisted the Power Plant by excavating the acid spill area. o Technicians responded to gas smell and carbon monoxide calls.

o Forced or planned outages — none.

Other activities have included:

0 16 Meters set, removed, locked, unlocked, dials or meters replaced;

0 7 Gas leak calls;

0 5 Carbon monoxide calls;

0 1 Meter and ERT changes;

o 233 Gopher State One Call requests; and

0 14 Miscellaneous service calls.

Water/District Energy

During the period: o Responded to 252 Gopher State One Call locate requests.

0 6 water service leaks were repaired.

0 1 hydrant repair made.

0 1 curb stop repaired. 0 2 gate boxes repaired.

0 2 steam services repaired.

o Routine steam and Water Plant maintenance.

o Routine vehicle maintenance.

Meter service this cycle included:

0 9 Meter replacements, 3 with 100w ERTs.

0 2 New meter site installations.

o 11 Read requests.

Water Filtration Plant Treatment Performance

Daily

Iron Fe Manganese Mn

Removal( Avg.) 97. 2% 92. 5%

Raw Supply Avg.) 1. 80 m / I 0. 685 m / I

Finished Water( Avg.) 0.05 m / I 0. 052 m / I

SDWA Recommended Maximum 0. 3 m / I 0. 05 m / I

25

Actual Reference Level

Chlorine CI Avg. Total 1. 1 m / I 0. 2 m / I < Cl < 4. 0 m / I

Crews worked on several water service leaks and maintained the temporary streetrepairs until the paving contractor gets them permanently repaired. Summer helpcontinued curb box GPS locating project averaging about 60 per day. Raw water pumping total for June 2018 was 65.24 MG, which compares to 80.40MG or 15. 2 MG less than June 2017. Daily demand ranged from a peak of 3. 14MGD on June 8 to a low of 1. 37 MGD on June 13 with an average of 2. 18 MGD. ForJune 58.97 million gallons of water were treated and pumped into the distribution

system.

Wastewater

Monthly activities included: 0 107. 4 million gallons of wastewater treated in June 2018.

0 491, 000 gallons of bio -solids processed in June 2018.

o Average Effluent Phosphorus for June 2018 - 0. 82 mg/ L. o The usual assortment of sampling, plant and lift station maintenance, and plant

operations.

o Bio -solids equipment maintenance.

o Summer maintenance projects.

o The Wastewater Lab Technician attended a Minnesota Wastewater Operators

Association Lab training June 20-21.

Wastewater Treatment

Plant Performance Summary June 2018

NPDES Permit Limits Actual Performance

Daily Monthly Weekly Avg. Daily Min Max

Effluent MGD 6. 77 NA NA 3. 58 2. 22 4. 85

Biochemical Oxygen

Demand ( BOD mg/1) 25 25 40 6. 0 4. 0 8. 0

Removal % 85 85 85 98.6 97.6 99.3

Total Suspended Solids

TSS mg/ 1) 30 30 45 9. 0 3. 0 26.0

Removal % 85 85 85 95.9 85.3 99. 1

Fecal ( or anisms/ 100ml) 400 200 200 148. 0 16. 0 2420. 0

NPDES Permit Limits Actual Performance

To date, 2, 788, 000 gallons of Bio - solids applied this year. Fecals/ Chlorine analyzed April

to October.

Administration/ Meter Reading

Meter reading began July 2 and was completed July 5. There were 19, 196 meters readin 40 hours this cycle as compared to 19, 162 meters read in 40 hours last cycle.

Energy ServicesCompiled information and letter to customer on unknown gas meter at residence.

Notified of owed amount to NUPU.

Compiled letter to customer regarding electric reclassification due to lower

consumption.

Continued work on Interconnection Process and Requirements for QualifyingFacilities contract.

Contacted local plumbing vendors regarding thermostatic valve replacement forsteam customers.

Contacted Center for Energy and Environment ( CEE) to discuss a possible joint

effort for home energy audits for customers. Gathered information and started 2019 budget.

Coded rebates and inspections.

Rebate applications processed during the period included: Energy Star Natural Gas Water Heater

1 rebate

Central Air Conditioning Check and Clean Rebate Program158 rebates

Central Air Conditioning Rebate Program12 rebates

Furnace Rebates

8 rebates

o 5 Furnaces

o 3 VSD

Programmable Thermostat Rebate

2 rebates

Energy Star Appliance Rebate14 rebates:

0 6 Dishwasher

0 3 Room AC Unit

0 4 Refrigerator

0 1 Electric Dryer

Energy Star Residential Lighting Rebate32 light bulbs replaced

4

Daily Monthly Weekly Avg. Daily Min Max

PH 6- 9 6- 9 6- 9 7. 4 7. 0 7. 6

Phosphorus ( m / 1) 1. 0 1. 0 1. 0 0. 82 0.40 1. 50

Chlorine Residual ( m / 1) 0.38 0. 38 0. 38 0.03 0.03 0. 03

Bio -solids Applied MG NA NA NA NA NA NA

Bio -solids in Storage (MG) NA NA NA 16,367 14,000 16, 500

To date, 2, 788, 000 gallons of Bio - solids applied this year. Fecals/ Chlorine analyzed April

to October.

Administration/ Meter Reading

Meter reading began July 2 and was completed July 5. There were 19, 196 meters readin 40 hours this cycle as compared to 19, 162 meters read in 40 hours last cycle.

Energy ServicesCompiled information and letter to customer on unknown gas meter at residence.

Notified of owed amount to NUPU.

Compiled letter to customer regarding electric reclassification due to lower

consumption.

Continued work on Interconnection Process and Requirements for QualifyingFacilities contract.

Contacted local plumbing vendors regarding thermostatic valve replacement forsteam customers.

Contacted Center for Energy and Environment ( CEE) to discuss a possible joint

effort for home energy audits for customers. Gathered information and started 2019 budget.

Coded rebates and inspections.

Rebate applications processed during the period included: Energy Star Natural Gas Water Heater

1 rebate

Central Air Conditioning Check and Clean Rebate Program158 rebates

Central Air Conditioning Rebate Program12 rebates

Furnace Rebates

8 rebates

o 5 Furnaces

o 3 VSD

Programmable Thermostat Rebate

2 rebates

Energy Star Appliance Rebate14 rebates:

0 6 Dishwasher

0 3 Room AC Unit

0 4 Refrigerator

0 1 Electric Dryer

Energy Star Residential Lighting Rebate32 light bulbs replaced

4

High Efficiency Lighting Rebate4 rebates

MVAC Low Income Program

1 individual assisted

o Through Wall AC Unit

Releaf Program

6 rebates

Engineering

Attended the Heartland Consumers Power District summer meeting. Status of EDD 20 -year Plan:

o Final report is being presented at the PUC meeting July 24. Wells 4 and 6 rehabilitation:

o The well testing has been done with the project punch list for closeout in thecontractor's hands.

Heinen Hill slope stability project: o Construction is complete.

o Working on an erosion control issue with the new seeding. Transmission line woodpecker damage assessment:

o Due to increasing cost estimates other options are being reviewed. MISO recognition of generation:

o Working on finding past MISO reports to use the short form of recognition ofthese assets.

IT ( Information Technology)

New phone system work continues. Many of the analog phone lines in hard to reachareas have been connected and set up. Testing for alarms and elevators iscontinuing. We had successful testing with some of the alarms but we are verifyingthat the solutions meet fire code requirements for alarm systems. There have been a

few issues with calls and certain phone numbers not working but we've been able toresolve them with Nuvera.

Long distance carrier for phone calls has been changed to Rochester TelecomSystems ( RTS). This decreases our per -minute rate from $. 11 to $. 058.

Migration to new social media archiving platform, PageFreezer, has been completed. Working to fulfill requests for new smartphones on accounts that are eligible forupgrades.

GIS technician John Bendix attended the 2018 ESRI User Conference July 9- 13. Hewas able to attend many education sessions and demonstrations of GIS solutionsbeing used today. It was also a chance to get hands- on demonstrations of some ofthe new features that will be available in upcoming versions that are gearedspecifically to utilities. Various printer and computer repairs. New purchases and equipment installs.

IT Stats

IT Tickets — We had 130 new tickets for support and projects in the last 30 days. Our

department was able to close out 136 tickets and 52 remain open as of July 19.

Security InformationAntivirus: There were 36 threats detected and stopped by antivirus in the last 30days.

Firewall:

o Intrusion Prevention System: 3, 300 intrusions detected and stopped.

o Gateway Antivirus: 0 viruseso Advanced Persistent Threat Detection: 0 threats detected

o Botnet blocker: 34 connections stopped

o Reputation Defense: 4,283 sites blocked

o Data Loss Prevention: 0 files denied

Spam filter: Of 28,655 email messages, 8, 810 were spam, 488 were blocked

because of administrative rules ( blacklist primarily), and 3 blocked for viruses.

Outages: No significant outages this month

Newsworthy items: There has been an increase in the number of phishing attacks onemployees utilizing fake invoices and malicious email attachments. The attachmentsare most often PDF files and made to look like an overdue or high- priority invoicethat needs to be paid. IT will be providing staff with additional training to help themrecognize the threats and avoid being compromised.

FINANCIAL PERFORMANCE

New Ulm Public Utilities is showing a preliminary net margin of $ 1, 450,650 for the six-

month period ended June 30, 2018, which compares to the annual budget of

1, 237,606.

Electric Division — Fund 710

The Electric Division is showing a preliminary net loss of $ 50, 545. This compares to

annual budgeted net margin of $ 108, 238. Sales are at approximately 48% of the annual

budget. Revenue is at 49% of the annual budget and expenses are at 49% of the annual

budget. Purchased power costs for the month of June were approximately $ 67. 33/ Mwhr. The average pooled natural gas rate for June was $ 2. 75/MCF.

District Energy Division — Fund 720

There was a preliminary net loss in the District Energy Division of $ 35,618, which

compares to an annual budget net loss of $ 23, 156. Sales are 63% of total budget.

Revenue is at 67% of total budget with expenses being approximately 70% of total

budget.

Natural Gas Division — Fund 730

The Natural Gas Division is showing a preliminary net margin of $ 1, 400,434, which

compares to the annual budgeted net income of $400,299. Total sales are approximately80% of the annual budget. Revenue is 75% of the annual budget with expenses at 61 %.

The pooled natural gas per MCF was $4.20.

Water Division — Fund 740

There was a preliminary net loss in the Water Division of $ 255. This compares to an

annual budgeted net income of $ 317, 975. Sales are at 45% of the annual budget.

Revenue is at 44% of budget with expenses at 49% of budget.

Wastewater Treatment Division — Fund 750

There is a preliminary net margin in the Wastewater Division of $ 132, 145, which

compares to a budget net margin of $ 397, 338. Revenue is at 48% of budget with

expenses at 50%.

C.

HUMAN RESOURCES ACTIVITIES

Staffing Activity

Interviews were conducted May 15 and 23 for an Electric System Technician with theElectric Distribution Department. An appointment is pending for July. Interviews were conducted June 4 and 5 for a Service Technician with the Gas

Department. An appointment is pending for July. Interviews were conducted June 11 and 12 for an Account Clerk with the Finance

Office. An appointment is pending for July. The application deadline for a Relief Boiler Operator with the Electric Production

Department was June 25. Interviews were conducted during July. The application deadline for Construction Chief with the Gas Department was June21. Interviews were conducted in July. The application deadline for Water/Steam Operator was June 11. This position will

be re -posted due to changing job requirements. Recruitment efforts continue for a Utilities Director with New Ulm Public Utilities.

Safety/Wellness

The Safety Committee held its monthly meeting on June 28 in the City Hall basementconference room. The Board of Accident and Injury Review presented a summary ofaccidents reported during May. Recommendations for hazard reduction will be

forwarded to the appropriate departments as required.

The quarterly safety/wellness seminar was held on June 27. Staff from Brown

County Public Health presented information on sun exposure/sunburn, tick-borneand mosquito -borne illnesses, heat related illnesses/ hydration, foodborne illness,

water safety, handwashing, current health trends/updates, and stress and healthysleep. In addition, a Dermascan machine was available that has a black light to showany signs of sun damage on a person' s face. The Minnesota Municipal Utilities Association safety training sessions during Juneincluded Silica and Excavation for Field Employees.

Injuries

No injury reports were received during June.

City Administration

Attended Coalition of Greater Minnesota Cities ( CGMC) Employee Relations meeting, met with employees about issue, attended a City Personnel Committee meeting, exitinterview conducted, attended special PUC meeting, exempt PUC group changed HealthCare Savings Plan ( HCSP) guidelines, background questionnaires given to police officer

finalists, written warning given to employee, work on various worker's compensationclaims, work on Walkingspree/walking challenge throughout the month, police officerbackground check requests, terminated employee, work on new phone system and set

up training for employees, oral warning given to employee, new job description written, pointed new position, talked with supervisor about employee issue, FMLA paperwork,

revised several job descriptions, working on issue with employee, second quarter

random drug/ alcohol tests conducted, and fair share fees for union members.

Employee of the Month

Recognized as the PUC " Employee of the Month" for June was Aaron Duchene,

Water/Steam Operator in the Water/Steam Department. Aaron has been employed byPublic Utilities since September 2014. He recently volunteered to assist at the Material

7

Distribution Center, and MDC staff stated that Aaron' s quick offer to help was of greatbenefit to them. He is a member of the Safety Committee and regularly performs his jobabove expectations.

Kudos — June employee anniversary dates:

Years

of

Service Name

17 Brian Gramentz

12 James Monroe

8 Jeff Pladsen

3 Patrick Kukla

3 Dan Pirsig

Department

City AdministrationElectric Distribution

Electric Production

Gas

PUC Administration

0

Position

City ManagerLine Worker

Plant Operator

Mechanic Welder

Utility Engineer

All Public Utilities Funds

City of New Ulm/ Public Utilities CommissionRevenues/ Expenditures and Commodities Summary Report

For Five Months Ended June 30, 2018

Preliminary

Year -to -Date Annual of Year -to -Date

Utilities Revenue

Actual Budget Annual Budget Previous Year Description

Revenue

20, 045, 801 37,293, 239 53. 8% 18, 917, 333 Utilities Revenue

639, 874 1, 085, 000 59. 0% 579, 825 Outside Utility Revenue2, 033,653 4,744, 719 42. 9% 1, 577, 589 Misc Revenue-

15, 320 0. 0% Grants

443, 128 344, 400 128.7% 270,245 Interest Revenue

23, 162,456 43,482,678 53.3% 21, 344, 992 Total Revenue

Expenditures

7, 094,498 13, 777, 219 51. 5% 6,450,411 Commodity -Purchased Power3, 636, 757 5, 889,435 61. 8% 3, 173, 831 Commodity -Fuel1, 837,770 3, 433, 870 53.5% 1, 731, 132 Production

196,830 452, 500 43. 5% 216, 507 Transmission

2,269, 832 4, 466,610 50.8% 2,263, 515 Distribution

53,945 104, 775 51. 5% 55, 364 Meters

37, 521 85,500 43. 9% 41, 699 Disposal

1, 078,774 1, 996, 550 54. 0% 948, 146 Treatment

58,792 116, 734 50.4% 56, 565 Customer Service

85,470 253, 000 33.8% 68, 396 Conservation Improvement Programs

103,754 267, 995 38.7% 125, 589 Storeroom

50,518 121, 415 41. 6% 68,357 Drafting4,237, 106 9, 338, 994 45.4% 4, 025,893 Administration

20, 741, 567 40, 304, 597 51. 5% 19,225,405 1 Total Expenditures

2, 420,889 1 3, 178, 081 1 76. 2% 11 2, 119, 587 1 Net Margin before in Lieu of Taxes

970,239 1 1, 940,475 1 50.0% 11 947, 374 1 Less Transfers in Lieu of Taxes

1, 450,650 1 $ 1, 237,606 1 117.2% 1 $ 1, 172,213 1 Net Margin after in Lieu of Taxes

2, 159,600 4,300, 000 50.2% 2, 064,850 Depreciation

1, 029, 185) ( 4, 949, 165) 20.8% 3, 549, 128) Capital Projects

804, 000) 0. 0% Bond Proceeds & Principal Payments

2, 581, 065 1 ( 215, 559) - 1197.4% 1 ( 312, 065) 1 Net Change in Cash

Electric Fund



Preliminary

Year -to -Date Annual of 11 Year -to -Date

Residential sales

Actual I Budget Annual Budget 11 Previous Year I Description

Commodities in Units ( MWH)

21, 501 45, 743 47. 0% 20,098 Residential sales

12, 408 26, 700 46. 5% 11, 798 Small Commercial sales

16, 986 35, 001 48. 5% 17,619 Large Commercial sales

39,036 79,434 49. 1% 36,412 Industrial sales

5, 666 10, 754 52. 7% 5, 272 Municipal PUC/ City sales95,597 197,632 48.4% 91, 199 Total Sales

99,694 199,469 50. 0% 97, 520 Total Purchases

Revenue

11, 132, 591 22, 863, 185 48.7% 10, 710,630 Utilities Revenue

202, 500 405,000 50.0% 202, 500 Outside Utility Revenue352, 385 801, 000 44.0% 77,478 Misc Revenue

6, 315 0. 0% Grants

82,780 57,000 145.2% 44,977 Interest Revenue

11, 770,256 24, 132, 500 48. 8% 11, 035,585 1 Total Revenue

Expenditures

7, 094,498 13, 777,219 51. 5% 6,450,411 Commodity -Purchased Power473,270 1, 299,247 36.4% 547,047 Commodity -Fuel

1, 026, 536 2, 238,400 45.9% 1, 008,710 Production

196,830 452,500 43. 5% 216, 507 Transmission

871, 701 1, 623, 500 53. 7% 896,595 Distribution

Meters

Disposal

Treatment

Customer Service

Conservation Improvement Programs

Storeroom

Drafting1, 579,214 3, 475,896 45.4% 1, 493,072 Administration

11, 242, 049 22, 866, 762 49.2% 10,612, 342 Total Expenditures

528, 207 1, 265, 738 41. 7% 423,243 Net Margin before in Lieu of Taxes

578, 752 1, 157,500 50. 0% 567, 000 Less Transfers in Lieu of Taxes

50, 545) 1 108, 238 1 - 46.7% 1 ( 143,757) 1 Net Margin after in Lieu of Taxes

912, 500 1, 825, 000 50. 0% 863, 500 Depreciation

476, 037) ( 1, 349, 555) 35. 3% 1, 392,409) Capital Projects


385, 9181 373, 6831 103.3% 1 ( 672,666) 1 Net Change in Cash

District Energy FundCity of New Ulm/ Public Utilities Commission

Period Revenues/ Expenditures and Commodities Summary ReportFor Five Months Ended June 30, 2018

Preliminary

Year -to -Date Annual % of 11 Year -to -Date

80, 092

Actual I Budget Annual Budget 11 Previous Year Description

Commodities in Units (MLB.)

82,469 112, 007 73.6% 80, 092 Plant Sendout

701 730 96. 0% 723 Residential sales


8, 890 11, 305 78.6% 8, 278 Large Commercial sales

46,895 84,652 55.4% 48,976 Industrial sales

2, 060 2, 127 96.9% 1, 715 Municipal PUC/ City69,730 109,898 63.4% 71, 251 ITotal sales

Revenue

593,372 906,917 65.4% 611, 474 Utilities Revenue

Outside Utility Revenue2, 514 2, 700 93. 1% 2, 011 Misc Revenue

95 Grants

33, 021 35,200 0. 0% 27,386 Interest Revenue

628, 907 944,912 66.67/. 640, 871 1 Total Revenue

Expenditures

Commodity -Purchased PowerCommodity -Fuel

502, 372 590, 170 85. 1% 395, 568 Production

Transmission

85,569 157, 530 54. 3% 66,923 Distribution

Meters

Disposal

Treatment

Customer Service


Storeroom

Drafting52, 832 172, 868 30.6% 96, 944 Administration

640, 773 920, 568 69.6% 559,435 Total Expenditures

11, 866) 24, 344 - 48. 7% 11 81, 436 Net Margin before in Lieu of Taxes

23,752 1 47, 500 50. 0% 11 27,000 Less Transfers in Lieu of Taxes

35, 618) ( 23, 156) 1 153. 8% 1 54,4361 Net Margin after in Lieu of Taxes

64,600 110,000 58. 7% 55, 000 IDepreciation5, 163) ( 516, 000) 1. 0% 12, 380) 1 Capital Projects

0. 0% JlBond Proceeds & Principal Payments

23,819 ( 429, 156) - 5. 6% 1 97, 056 1 Net Change in Cash

Natural Gas Fund



Preliminary


Residential sales

Actual I Budget Annual Budget Previous Year I Description

Commodities in Units (dtherms)

338,735 414, 000 81. 8% 307,319 Residential sales

3,498 3,610 96.9% 2, 527 Small commerical sales

147, 325 171, 100 86. 1% 129, 131 Large commercial sales

233, 533 325,800 71. 7% 217,225 Industrial sales

18,468 20,790 88. 8% 16, 769 Municipal PUC/ Cit

741, 559 935,300 79. 3% 672, 971 Total sales

142, 967 337,044 42.4% 154, 272 1 Power plant gas transported

Revenue

5, 229,803 6, 937,833 75.4% 4, 553,708 Utilities Revenue

437,374 680,000 64.3% 377,325 Outside Utility Revenue64,517 81, 500 79.2% 22,866 Misc Revenue

1, 900 0. 0% Grants

118, 594 94,400 125.6% 72, 896 Interest Revenue

5, 850,288 7, 795,633 75.0% 5-,0-26-,-79-5- F- Total Revenue

Expenditures

Commodit - Purchased Power

3, 163,487 4, 590, 188 68. 9% 2, 626, 784 Commodity -FuelProduction

Transmission

514,721 1, 084, 100 47. 5% 535,672 Distribution

Meters

Disposal

Treatment

Customer Service


Storeroom

Drafting577, 148 1, 332, 046 43. 3% 577,498 Administration

4, 255,356 7, 006, 334 60.7% 3, 739, 954 Total Expenditures

1, 594,932 789,299 202. 1% 1, 286, 841 Net Margin before in Lieu of Taxes

194,498 389, 000 50. 0% 182, 002 Less Transfers in Lieu of Taxes

1, 400,4341 400,2991 349.8% 1 1, 104, 839 1 Net Margin after in Lieu of Taxes

185,000 370,000 50. 0% 185,000 Depreciation

80, 198) ( 467, 500) 17. 2% I 81, 238) Capital Projects

0. 0% Bond Proceeds & Principal Payments

1, 505,2361 302,7991 497. 1% 1 1, 208, 601 1 Net Change in Cash

Water Fund



Preliminary


Residential sales

Actuals I Budget Annual Budget 11 Previous Year Description

Commodities in Units ( KGAL)

106,780 243,534 43. 8% 104, 852 Residential sales


44,753 111, 705 40. 1% 46, 026 Large Commercial sales

89,393 159,730 56.0% 83,626 Industrial sales

8,652 32,425 26.7% 10, 640 Municipal PUC/ City sales265,470 584,903 45.4% 11 260, 980 ITotal sales

Revenue

1, 307,465 2, 860,804 45. 7% 1, 292, 877 Utilities Revenue

Outside Utility Revenue70,606 348,674 20. 2% 49, 102 Misc Revenue

1, 500 0. 0% Grants

45,300 35,600 127. 2% 28,448 Interest Revenue

1, 423, 371 3, 246,578 43. 8% 1, 370,427 1 Total Revenue

Expenditures

Commodity -Purchased PowerCommodity -Fuel

308, 862 605, 300 51. 0% 326, 854 Production

Transmission

677,058 1, 304,280 51. 9% 618,773 Distribution

Meters

Disposal

Treatment

Customer Service


Storeroom

Drafting362, 458 868, 523 41. 7% 364,266 Administration

1, 348,378 2, 778, 103 48. 5% 1, 309, 893 Total Expenditures

74,993 468,475 16. 0% 11 60, 534 Net Margin before in Lieu of Taxes

75,248 150, 500 50. 0% 11 77,498 Less Transfers in Lieu of Taxes

255) 1 317, 975 - 0. 1% 1 ( 16, 964) 1 Net Margin after in Lieu of Taxes

407, 500 815, 000 50.0% 400,000 Depreciation

205,088) ( 1, 161, 000) 17.7% 175, 876) Capital Projects


202, 157 ( 213, 025) - 94. 9% 1 207, 1601 Net Change in Cash

Wastewater Treatment Fund

City of New Ulm/ Public Utilities CommissionRevenues/Expenditures and Commodities Summary Report


Preliminary

Year -to -Date Annual of Year -To -Date

Utilities Revenue


Revenue

1, 782,570 3, 724,500 47. 9% 1, 748,644 Utilities Revenue

Outside Revenue

96,278 345, 974 27. 8% 70,215 Misc Revenue

2,000 0. 0% Grants

120, 198 85,700 140.3% 66, 163 Interest Revenue

1, 999,046 4, 158, 174 48. 1% 1, 885,022 1 Total Revenue

Expenditures

Commodity -Purchased PowerCommodity -FuelProduction

Transmission

120,783 297,200 40.6% 145,552 Distribution

Meters

37, 521 85,500 43.9% 41, 699 Disposal

1, 078, 774 1, 996,550 54.0% 948, 146 Treatment

Customer Service


Storeroom

Drafting531, 834 1, 185,611 44.9% 430,900 Administration

1, 768, 912 3, 564,861 49.6% 1, 566,297 Total Expenditures

230, 134 593,313 38.8% 318,725 Net Margin before in Lieu of Taxes

97,989 195,975 50. 0% 93,874 Less Transfers in Lieu of Taxes

132, 1451 397,3381 33. 3% 1 224, 851 1 Net Margin after in Lieu of Taxes

500,000 1, 000,000 50.0% 475,000 Depreciation

147,740) ( 777, 1101 19. 0% 1, 820,738) Capital Projects

409,000) 0. 0% Bond Proceeds & Principal Payments

484,405 1 211, 2281 229.3% 1 ( 1, 120,887) 1 Net Change in Cash

Administration Fund



Preliminary


Actuals I Budget I Annual Bud et Previous Year Description

Revenue

Utilities Revenue

Outside Utility Revenue1, 187,865 2, 645,921 44. 9% 1, 173,455 Misc Revenue

3, 100 0. 0% Grants

35, 825 30, 700 116. 7% 25,578 Interest Revenue

1, 223,690 2, 679,721 45. 7% 1, 199,033 1 Total Revenue

Expenditures


Transmission

Distribution

53,945 104,775 51. 5% 55,364 Meters

Disposal

Treatment

58, 792 116,734 50.4% 56, 565 Customer Service

85,470 253,000 33.8% 68, 396 Conservation Improvement Programs

103, 754 267,995 38.7% 125, 589 Storeroom

50, 518 121, 415 41. 6% 68, 357 Drafting850,373 1, 785, 100 47.6% 829,050 Administration

1, 202,852 2, 649,019 45.4% 1, 203,321 1 Total Expenditures

20, 838 1 30, 702 - 11 ( 4, 288) 1 Net Margin before in Lieu of Taxes

11 - I Less Transfers in Lieu of Taxes

20, 838 1 30, 702 1 - 11 ( 4, 288) 1 Net Margin after in Lieu of Taxes

55, 000 110,000 50. 0% 56, 350 Depreciation

38,459) ( 556,000) 6.9% 43,526) Capital Projects


37, 379 1 ( 415,298) - 9. 0% 1 8, 536 1 Net Change in Cash

Information Technology FundCity of New Ulm/ Public Utilities Commission

Period Revenues/ Expenditures and Commodities Summary ReportFor Five Months Ended June 30, 2018

Preliminary



Revenue

Utilities Revenue

Outside Utility Revenue259,488 518,950 50. 0% 182,462 Misc Revenue

410 0. 0% Grants

7, 410 5, 800 0. 0% 4,797 Interest Revenue

266,898 525, 160 50. 8% 187,259 1 Total Revenue

Expenditures


Transmission

Distribution

Meters

Disposal

Treatment

Customer Service


Storeroom

Drafting283,247 518, 950 54.6% 234, 163 jAdministration283,247 518,950 54.6% 234, 163 1 Total Expenditures

16, 349) 1 61210 1 - 263.3% 11 ( 46, 904) 1 Net Margin before in Lieu of Taxes

I - 11 - I Less Transfers in Lieu of Taxes

16, 349) 6,210 - 263.3% 1 ( 46, 904) 1 Net Margin after in Lieu of Taxes

35,000 70,000 0. 0% 30, 000 Depreciation

76, 500) ( 122, 000) 62.7% 22, 961) Capital Projects


57, 849) ( 45,790) 1 126. 3% 1 ( 39, 865) 1 --- Net Change in Cash

City of New Ulm / New Ulm Public Utilities CommissionInvestment Summary

As of

June 30, 2018

r.=„ e. CI IAID

InterestData Maturity 1 day Interest at

Ameunt Yield Invested Date vWd Maturity

Investment Portfolio Weighted Average Yield

Investment Portfolio Weighted Average Coupon

Other Accounts:

Operating Account Citizens Bank i

NO not callable

A called annuallyS called semiannually

Q called quartertyM called monthlyC called confinuously

C10 called confinuously, 10 day noticenrep - y N - J tg- V called confinuously, 5 day notice

monthly P31 pmts

NO Com ass Bk Birmingham SHTM NT 20451PAUO Oppenheimer 245 000.00 1. 550% 7/ 102013 7/ 102018 10.40 18997.90

NO Bank Bennington - VT 060676BD4 MBS Securities 245 000.00 1. 500% 7/ 172013 7/ 172018 10. 07 18 385. 07

NO Interaudi Bk New York - NY 45842PAB7 Oppenheimer 245 000.00 1. 550% 7/ 172013 7/ 172018 10.40 18 997. 90

NO Mercantil Commercebank National Association - FL 58733AAMI Morgan Stanley 245 000.00 1. 750% 7242013 7242018 11. 75 21 449. 25

NO WEX Bank Midvale - UT 92937CDY1 MBS Securities 245 000.00 1. 000% 7292016 7/ 302018 6. 71 4,9D6. 71

NO Aly Bank Midvale - UT 02006LST11 Mor an Stanley 245 000.00 1. 700% 8/62015 8/62018 11. 41 12 506. 41

NO Enerbank USA - UT 29266NC47 Oppenheimer 245 000.00 1. 700% 9292014 9282018 11. 41 16 660. 00

NO Lincoln 1st Bank Lincoln Park - NJ 53362LAJ3 MBS Severities 245 000.00 1. 100% 9/ 302016 9282018 7. 38 5, 375b23

NCI First Bank Richmond National Asan 319267FT2 MBS Severities 245 000.00 1. 100% 9/302016 9282018 7. 38 5, 375. 23

NCI Bank Baroda CD New York NY CD 0606244X8 Mor an Stanley 245 000.00 2. 000% 10/ 12013 10/92018 13. 42 24 620. 82

NO Sallie Mae Bank Sall Lake C' - UT 795450WN1 MBS Severities 245 000.00 1. 650% 10/ 72015 10/92018 11. 08 12160.73

NO Park Natinal Bank Newark - OH 700654AV8 Oppenheimer 245 000.00 24100% 9262014 3262019 14. 10 23 145. 45

NO Webbank Sah Lake C - UT 947547JF3 MBS Severities 245 000.00 1. 250% 9282016 3282019 8. 39 7, 643. 66

NO Flushing Bank Flushing - NY 34387ABF5 Morgan Stanley 245 000.00 1. 450% 4/ 15/ 2015 4/ 152019 9. 73 14 219. 73

NO vlerchants 8 Farmers Bank 8 Trust Co, Leesville - LA 588211AD4 MBS Securities 245 000.00 1. 100% 10252016 4252019 7. 38 fi 733. 81

NO Of Bk Sah Lake C' - UT 17284AV39 Wells Fargo Advisers 245 000.00 2. 100% 6/62012 6/62019 14. 10 36 029. 10

NO Word Finl Capt Sah Lake C' - UT 98146QDA6 Morgan Stanley 245 000.00 1, 600% 7/ 102012 7/ 122019 10. 74 27 472. 22

NO Abacus Federal Savings Bank - NY 00257TAW6 MBS Securities 245 000.00 1. 100% 729/2016 729/2019 7. 38 8, 085. 00

NO American Express Sall Lake C' - UT 02587CAM2 Morgan Stanley 245 000.00 2. 050% 7/ 31/ 2014 7/ 312019 13. 76 25 126.26

NO Ohio Valley Bk CO Gallipolis Ohio 677721CG5 MBS Securities 245 000.00 1. 850% 9/ 122014 9/52019 12. 42 22 587. 99

NCI Capital One Bank Glen Allen - VA 140420PI76 Morgan Stanley 245 000.00 1. 950% 9/ 172014 9/ 172019 13. 09 23 900. 59

NO Peoples UTD Bk Bridgeport - CT 71270QGU4 MBS Securities 245 000.00 2. 000% 9/ 172014 9/ 172019 13. 42 24 513. 42

NO Machias Savings Bank - ME 554479DO5 MBS Securities 245 000.00 1. 900% 9/ 172014 9/ 172019 12. 75 23 287. 75

NO Bank Leumi USA New York - NY 063248FY9 MBS Securities 245000.00 1. 250% 9272016 9272019 8. 39 9187.50

NO tat Merchants Bank Munchie - IN 32082BDS5 Morgan Stanley 245 000.00 2. 000% 9/ 302014 9/ 302019 13. 42 24 513.42

NO First Source Bank South Bend - IN 33646CFT6 Oppenheimer 245 000.00 1. 500% 10/ 142015 10/ 152019 10. 07 14 720. 14

NO First International Bank & Trus[ Watford City 32057GAE9 Oppenheimer 245 000.00 1. 600% 10/ 162015 1/ 162020 10. 74 16 678. 79

NO Goldman Sachs BK USA - NY 38148JHQ7 Wells Fargo Advisers 245 000.00 2. 100% 1212015 1212020 14. 10 25 739. 10

NO Lakeside Bank Chicago - IL 51210SLB1 Oppenheimer 245 000.00 1. 500% 1292016 1292020 10. 07 14 710. 07

NO Riverwood Bank Bemidji - MN 76951 DAPS MBS Securities 100 000.00 1. 650% 10/2/ 2015 3/ 302020 4. 52 7, 418.22

NO Rolistone Bank Fitchburg - MD 77579ABM7 Morgan Stanley 245 000.00 1. 750% 4/ 152015 4/ 152020 11. 75 21 460. 99

NCI Capital One National Assn - VA 14042E4P2 Oppenheimer 245 000.00 2. 300% 7/152015 7/ 152020 15. 44 26 205. 88

NO Words Foremost Bank Sydney - NE 981571 BPS MBS Securities 200 000.00 2. 400% 7/ 162015 7/ 162020 13. 15 24 026. 30

NO Banco Poplar - NY 05965GUKO Oppenheimer 161000.00 2. 300% 8/ 122015 8/ 122020 10. 15 18535.29

NO Bank Midwest Spirit Lake - IA 063615BC1 Oppenheimer 245 000.00 1. 750% 10/142015 8/ 142020 11. 75 20 744.45

10/ 022018 S Frontenac Bank Earth C' - MO 35903SCY6 Oppenheimer 245 000.00 1. 850% 10/2/ 2015 1022020 12. 42 22 687. 34

NO bmw Sah Lake C - UT 05580ADQ4 Mor an Stanley 245 000.00 2.100% 11= 016 1222021 14. 10 25 753. 19

NO Barclays Bank Wilmin on - DE 06740KKCO Morgan Stanley 245 000.00 2.000% 7/ 12/2017 7/ 122021 13. 42 19 613.42

NO third federal Cleveland - OH 88413OBN7 Oppenheimer 245000.00 2.000% 7282017 7282021 13. 42 19613.42

NO Medallion Bank - UT 58404DAB7 Mor an Stanley 245 000.00 2.000% 8/ 72017 8/ 62021 13. 42 19 600. 00

NO Beneficial Mutual Savin - PA 081730BR6 Oppenheimer 245 000.00 1. 500% 9/ 122016 9/ 132021 10. 07 18 395. 14

NO EverBank Jacksonville - FL 29976DS27 Oppenheimer 245 000.00 1. 550% 9/ 132016 9/ 132021 10. 40 18 997. 90

NCI Happy State Bank Ha - TX 411394AN9 MBS Securities 245 000.00 1. 500% 9/ 162016 9/ 162021 10. 07 18 385. 07

NCI State Bank of India New York - NY 8562845X8 MBS Securities 182 000.00 2.300% 712 2017 1262022 11. 47 18 877. 14

NO Washington County Bank 93754PAN7 Oppenheimer 245 000.00 2.000% 8/ 112017 5/ 112022 13. 42 23 278. 36

NO tat Bank of Highland Park - IL 319141GP6 MBS Securities 245 000.00 2.050% 6282017 6282022 13. 76 25 126.26

NO Citizens Bank CD 86427 CNzens Bank 2, 000,000.00 2.350 % 6/ 302017 6/ 302022 128.77 235 128. 77

NO Citizens Bank CD 86685 CNzens Bank 500 000.00 1. 750% 9/ 132017 9/ 122020 23.97 26 250. 00

NO Citizens Bank CD 86686 CNzens Bank 750 000.00 2. 000% 9/ 132017 9/ 132021 41. 10 60 041. 10

NO Citizens Bank CD 86687 Citizens Bank 750 000.00 2. 250% 9/ 132017 9/ 132022 46.23 84 421. 23

NO Commenity Bank Jumbo 20099AMLS Morgan Stanley 200 000.00 2. 300% 7/ 52017 7/ 52022 12. 60 23 012.60

NO discover, Greenwood - DE 2546725E4 Morgan Stanley 245 000.00 2.200% 7/62017 7/ 62022 14. 77 26 964. 77

NO International Bank Chicago - IL 45906ABPI MBS Securities 245 000.00 2. 100% 7/ 312017 7292022 14. 10 25 710.90

NO First Western Bank Booneville - AR 33749VAR9 MBS Securities 245 000.00 2.050% 7/ 312017 7292022 13. 76 25 098.74

NCI Enterprise Bank - PA 29367RJS6 MBS Securities 245 000.00 2. 050% 7/ 312017 7292022 13. 76 25 098.74

NCI Wells Faro Bk NA Sioux Falls 949763LR5 MBS Securities 245 000.00 2.500% 12/82017 12/ 82022 16. 78 30 641. 78

NO Mountain Amer Fed OR UN West Jordan UT 62384RAE6 MBS Securities 245 000.00 2.400% 12282017 12282022 16. 11 29 416. 11

NO American Express Centurion Sait Lake C' - UT 02587DV47 Morgan Stanley 245 000.00 2. 350% 8/ 82017 8/ 82022 15. 77 28 803.27

NO Industrial & Commercial Bank of China USA - NY 45581 EAH4 Morgan Stanley 245 000.00 2. 350% 7282017 7282023 15. 77 34 560.77

07272018 Federal Home Loan Mtq Corp3134GBZS4 Oppenheimer 1, 000,000.00 2. 150 % 7272017 4272022 58.90 102 198.63

07/042018 C5 Federal Home Loan Bank 3130A9NN7 Morgan Stanley 1, 000,000.00 1. 650% 10/ 192016 4/ 192022 45.21 90 772.60

07/042018 C5 Federal Farm Credit Banks 3133EFX44 Morgan 8 nley 1, 000,000.00 2. 050% 4/ 52016 10/ 52022 56. 16 133 334.25

07/ 162018 Webster Five Cents Savings Bank - MA 94789PBU7 Oppenheimer 245 000.00 1. 800% 12/ 162015 6/ 162020 12. 08 19 863. 12

07262018

07272018

QM

Federal National Mort a e Association

Fortune Bank Arnold - MO 3136G4DL434969RBG2 MBS SecuritiesMor an Stanley

1 000 000.00

245 000.00 1. 250%

10262016 10262021

3272013 3272019

27.40

8. 39

50 027.40

18 383.39

07/28120181 Orrstown Bank Shi ensbur - PA 687377DS7 Wells Fargo Advisers 245 000. 00 2. 000% 8282015 8282020 13. 42 24 526.85

07/28120181 M1 First Oklahoma Bank Tulsa - OK 335857AS7 Oppenheimer 245 000.00 1. 850% 1282016 1282021 12. 42 22 687.34

0728201807282018

Q Federal Home Loan Mortgage Co

Federal Home Loan Mortgage Co

3134GASR6

3134GASK1

Wells Fargo Advisers

Wells Far o Advisers

1. 1005 000.00

P() 0 000.00

10282016 10282021

10282016 10282021

27.40

27.40

50 027.40

50 027.40

07292018 5C5 Federal Farm Credit Banks 3133EGQB4 MBS Secures 3 000 000.00 1. 730% 8/ 82016 2/ 82023 142. 19 337 705.48

07/092018 M BOKF NA., Tulsa - OK 05572YDW9 Mor an Stanle 245000.00 2.100% 3/ 92016 3/ 92023 14. 10 36029. 10

08242018

08252018 Q

Federal Home Loan Morta e Co

Federal Home Loan Mtg Corp

3134GADQ4 Wells Far o Advisers

313469X44 O enheimer

1 . 00.. 52 000 000.00 1. 625%

8242016

8252016

8242021

8252021

37.67

89.04

68 787.67

162 589. 04

03292018 Bankcham ai n Nab Assn Cham ai n - IL 06607ABF7 Stifel Nicolaus 245 000.00 1. 200% 10292015 10292018 8. 05 8828.05

08/312018 JP Morgan, Columbus - OH 48126XCR4 Morgan Stanley245000.00 1. 600% 8/ 312016 8/ 312021 10. 74 19610. 74

09/082018 Q

Q

Federal Home Loan Mt CoFirst SavingsBank Renton - WA

3134GADB7

33621JAJ7

Mor an StanleyO enheimer

1 000 000.00

245000.00 1. 600%

9/ 82016

9/ 192014

9/ 82023

9/ 192018

34.2510. 74

87 534.25

15690. 74

09222018 all Signature Bk CD Chica o - IL 82669VBT7 Mor an Stanle 245 0. 00 1. 300% 3222013 3222019 8. 73 19 118. 73

09282018

09/302018

Q

QAFederal Home Loan Mo a e CoFederal Home Loan Mortgage Co

Gulf Coast Bank 8 Trust

3134GAHG2

3134GALY8

402194FB5

Mor an S[ anle

WeIIs Far o Advisers

MBS Securities

1.,. 0: 902.6 .001, 120,000.00

240 000.00

9282016 9282021iiiiilli 9/ 302016 9/ 302021

1250% 10202016 10/ 152019

41. 1030.68

8. 22

75 041. 10

56 030.68

8 958.90

07/ 192018

0824201807242018

Q

Q

Federal Home Loan Mort a e CoFederal Home Loan Bank

Northern Bank & Trust CD WoburnMA

3134GBVF6

3130ABXK7

66476Q8T4

Wells Far; o Advisers

Wells Far12 AdvisersWells Far o Advisers

1 000 000.00

9o0 000.00245 000. 00 2. 000%

7/ 192017

8242017

2242017

7/ 1920228242022

8242021

54.7954.25

13. 42

100 054. 79

99 054.25

22 043.29

07/042018 S Federal Farm Credit Banks 3133EHPM9 Mor an Stanle 1 000 000.00 2. 280% 6282017 6262023 62.47 136 737. 53

08/042018 Texas Exchange Bank SSB 88241TBT6 Wells Farno Advisers 245 000.00 2. 050% 8/42017 8/ 42021 13. 76 20 103.76

08/082018 Commerce Bank Geneva 20056QQN6 Wells Far o Advisers 245 000.00 2. 000% 8/ 82017 2/ 82022 13. 42 22 083. 56

07292018 CS Federal Farm Credit Banks 3133EHXZ1 MBS Securities 1, 000,000.00 2. 000% 9/ 122017 9/ 122022 54.79 100 054.79

08113/ 20181 Fxchan a Bank Gibbon NE 301074CMO Wells Far o Advisers 245,000 2. 050 % 9/ 132017 9/ 132022 13. 76 25 126.26

12/ 13/2018 Thomaston Svn Bk CD 88457PAK3 WeIIs Far o Advisers 245,000: 000 2. 350 % 12/ 132017 12/ 132022 15. 77 28 803.27

C5 Federal Farm Credit Banks 3133EHXMO Oppenheimer 1, 000,000.00 1. 930% 9/ 132017 12/ 62021 52. 88 81 694. 52

First Bank of PR Santurce 33767A5A5 O enheimer 245 000.00 2. 200 % 9202017 9202022 14. 77 26 964.77

Pinnacle Bk Nashville Tenn 72345SFU0 Oppenheimer 245 000.00 1. 950% 9212017 9212021 13. 09 19 123.09

Merrick Bk South Jordan Utah 59013' 832 O enheimer 245 000.00 2. 050% 9222017 9222022 13. 76 25 126.26

East Boston Savings Bank 27113PBX8 O enheimer 245 000.00 2. 000 % 91282017 9282022 13. 42 24513

NO FNMA 31374TZ85 Well. Far oAdvisers 1818 7. 000% 11/ 132000 10/ 12020 0. 35

NO FNMA 31374GNS2 Wells Fargo Advisers 518.0010/232000 10232020 0. 48

NC FNMA 31383JXL9 Wells Far oAdvisers 4, H. 2 7. 000% 10/ 272000 10272020 0. 83

Investment Portfolio Weighted Average Yield

Investment Portfolio Weighted Average Coupon

Other Accounts:

Operating Account Citizens Bank i

NO not callable

A called annuallyS called semiannually

Q called quartertyM called monthlyC called confinuously

C10 called confinuously, 10 day noticenrep - y N - J tg- V called confinuously, 5 day notice

monthly P31 pmts

is i a. z. 0 i, oa

1. 75%

0. 00%

a 4a

14,958, 351. 33

2.1800% 90 day Trees constant maturities average from prev month + 25 basis points

Ol/ 11ltOra

City of New Ulm / New Ulm Public Utilities CommissionSummary of Investment Pool

As of

June 30, 2018

Total Investments 42, 271, 685. 68 1 100. 01% 1 1. 746%

TERM OF INVESTMENT

Amount

Percent

of Total

Average

Interest

Rate

Average

Size

Average

Days to

MaturityLess than 6 months 0. 00 0. 00%

7 to 12 months 0. 00 0. 00%

1 to 2 Years 490,000.00 1. 16% 1. 099% 245,000 90

2 to 3 Years 1, 965,000.00 4.65% 1 1. 308% 280,714 389

3 to 4 Years 3,690,000.00 8. 73% 1 1. 787% 283, 846 626

4 to 5 Years 27,403,000.00 64.83% 1. 770% 449,230 1031

5 to 6 Years 2, 980,000.00 7. 05% 1. 886% 496,667 950

Over 6 Years 5, 743,685.68 13. 59% 1. 736% 638, 187 1121

Total Investments 42, 271, 685. 68 1 100. 01% 1 1. 746%

Total Investments 42, 271, 685. 68 1 100. 00% 1 98

AMOUNT INVESTED BY INSTITUTION:

Amount

Percent

Of Total

Average

Interest

Rate

Number of

Investments

Average

Term (days)

Citizens 4,000,000.00 9.46% 2. 191% 4 1, 552

United Prairie Bank 0. 00 0. 00% 0

E. D. Jones 0. 00 0. 00% 0

Alliance Bank 0. 00 0. 00% 0

Stifel Nicolaus 245,000.00 0. 58% 1 1. 199% 1 1, 096

MBS Securities 10,377,000.00 24. 55% 1. 663% 26 1, 523

Wells Fargo Advisers 7, 988,685.68 18. 90% 1. 579% 17 2,790

Frandsen Bank & Trust 0. 00 0. 00% 0

Mor anStanle Smith Barney 10,355, 000.00 24. 50% 1. 727% 25 1, 929

Oppenheimer1

9, 306,000. 00 22. 01% 1. 825% 25 1, 692

Total Investments 42, 271, 685. 68 1 100. 00% 1 98

DAYS TO MATURITY:

Amount Percent

Total within

one year

One Month or less 1, 225,000. 00 2. 90%

4, 900,000.00Between 1 & 2 Months 245,000. 00 0. 58%

Between 2 & 3 Months 980,000. 00 2. 32% 11. 60%

4 to 6 Months 735,000.00 1. 74%

7 to 9 Months 980,000.00 2. 32%

10 to 12 Months 735,000.00 1. 74%

1 to 2 Years 4, 015,000.00 9. 50%

2 to 3 Years 2, 339,685.68 5. 53%

3 to 4 Years 17, 737,000.00 41. 96%

4 to 5 Years 12, 035,000.00 28.47%

Over 5 Years 1, 245,000.00 2. 95%

Total Investments 42, 271, 685.68 100.01%


Meeting Date: July 24, 2018 Agenda Item Number: 2. b.

Agenda Section: Receive from Officers,

Boards and Commissions Originating Department: Electric Distribution

Resolution: N/A Prepared By: Dan Pirsig

Number of Attachments: One Presented By: Jarrod Luze of DGR

Item• Presentation by Jarrod Luze of DGR Engineering regarding New Ulm' s Electric SystemStudy and 20 Year Capital Improvements Plan.


Motion by , second by to receive the presentation on New Ulm' s Electric

System Study and 20 Year Capital Improvements Plan, by Jarrod Luze with DGR Engineering.


Overview:

DGR Engineering was hired in 2017 to study New Ulm' s existing electrical system. This study is designed to look atNew Ulm' s current system configuration and loading, projected growth and future needs, and then inform PUC staff ofpotential shortcomings in the system and recommend projects that alleviate the issues while complementing the futuregoals of the utility. This analysis will be accomplished by using internal GIS data, SCADA logs and drawings of record.

This type of 20 -year study has been done at the PUC before on a regular basis, on a five- to 10 -year schedule. Thefrequency is to keep on top of the changing system conditions and system demands. The past studies have forecastedhealthy growth with constant usage pattern. The current electric growth industry wide is relatively flat unless there is anaddition of new customers. The usage pattern is changing with the development ofdistributed generation (solar) and moreefficient technologies.

Primary Issues/Alternatives to Consider:


Attachments:

New Ulm' s Electric System Study and 20 Year Capital Improvements Plan

ELECTRIC SYSTEM STUDY &

20 YEAR CAPITAL

IMPROVEMENTS PLAN

IDNEWLl I

ENGINEERING

New Ulm Public Utilities

Prepared byDGR Engineering

July 2018

DGR Project No. 426301

ELECTRIC SYSTEM STUDY &

20 YEAR CAPITAL IMPROVEMENTS PLAN

FOR

NEW ULM PUBLIC UTILITIES

NEW ULM, MINNESOTA

July 2018

I hereby certify that this plan, specification or reportwas prepared by me or under my direct supervision andthat I am a duly Licensed Professional Engineer underthe laws of the State of Minnesota.

Signature.

Jarrod D. Luze

Date: 7/ 20/ 2018 License No. 51540

DGR Project No. 426301

DGR Engineering1302 South Union Street

Rock Rapids, IA

712) 472- 2531

[email protected]

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Table of Contents

Electric System Study & 20 Year Capital Improvements PlanNew Ulm Public Utilities, New Ulm, Minnesota

Executive Summary

Tab 1 Introduction

Tab 2 Load Growth Projections

Tab 3 Design Criteria

Tab 4 Existing System Analysis

Tab 5 Capital Improvements Plan

Tab 6 Recommendations and Conclusions

Tab T Appendix A

Figure 4: 20 Year Load Growth Projections

Figure 5: Existing Electric System MapFigure 6: 20 Year Capital Improvements Map

Tab 8 Appendix B

Figure 7: Existing Electric System One -line DiagramFigure 8: 20 Year Capital Improvements One -line Diagram

Tab 9 Appendix C

Case Study Summaries

Existing System & Existing Load

Existing System & Proposed Load

Proposed System & Proposed Load

MMM4 Electrical System Study & Capital Improvements Plan


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Executive Summary

INTRODUCTION AND SCOPE

New Ulm Public Utilities ( NUPU), of New Ulm, Minnesota owns and operates an electric system that

provides electric service to the businesses and citizens of New Ulm. DGR Engineering ( DGR) was

commissioned to perform a system evaluation and planning study for NUPU.

It has been approximately ten ( 10) years since a system -wide assessment has been completed forNUPU' s electric system. Since then, several changes have occurred on the system and an updated

study is necessary to account for these changes in NUPU' s planning process. Analysis of NUPU' s

electric system in this study includes the 69 kV transmission, 13. 2 kV distribution and substation

facilities located within the City of New Ulm, which are owned and operated by NUPU. A high- level

assessment of the interconnected 69 kV transmission facilities immediately surrounding New Ulm is

also included in this study as it relates to the supply of 69 kV transmission to NUPU. This reportoutlines analysis of NUPU' s system and presents capital improvements projects recommended to

eliminate deficiencies identified under existing and future system conditions. The Capital

Improvements Plan ( CIP) covers a twenty-year period and provides cost estimates for fiscal planning.

LOAD GROWTH AND EXISTING SYSTEM

Historical load data was obtained from NUPU staff for the ten- year period from 2007 through 2017.

Based on the demand and energy data received, the annual summer and winter peak demand

generally remained steady with an average summer peak of 44.9 MW and average winter peak of29. 7 MW. There was mild fluctuation with a maximum 48.5 MW peak demand in the summer of

2011. NUPU usually reaches its peak demand during the summer months of July or August. Thepeak winter demand was seen in November of 2016, with a peak demand of 33. 3 MW. Based on

discussion with NUPU staff regarding the upcoming planned potential load developments, a loadgrowth rate of 1. 5% was utilized in forecasting load across the 20 -year period of this study. Basedon an annual growth rate of 1. 5%, the the summer peak system demand is estimated to add

approximately 17 MW over the next 20 years, from a 2017 peak of 45. 8 MW to a peak of 62. 9 kWin 2038. The historical and projected system demand requirements are shown in Figure 1.

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Electrical System Study & Capital Improvements Plan


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Executive Summary

FIGURE 1

SYSTEM DEMAND REQUIREMENTS


70,000

65,000

60,000

55,000

i50,000 p

sZ45,000 W

O

40,000 Qa.

35,000

30,000

25,000

20,000

2007 2009 2011 2013 2015 2017 2019 2021 2023 2025 2027 2029 2031 2033 2035 2037

YEAR

NisttKical 1Ni+xer E emand- 4-->Lorrc a! Summer Lrerna+;J

Projected Winter Demaid ...{ Projetted Sommer Dc mane:

The NUPU electric system consists of 69 kV transmission lines, four ( 4) load -serving substations,

seventy-three ( 73) MW of generation capacity, nineteen ( 19) 13. 2 kV distribution feeders, and two2) large 13. 2 kV express feeders. The transmission system is comprised of a 69 kV network fed

from two ( 2) radial 69 kV transmission lines from Xcel Energy's West New Ulm and Ft. Ridgely

substations. The existing distribution system provides electric service throughout New Ulm at13. 2 kV. NUPU also owns a small 2. 4 kV distribution network located at the Power Plant substation

that is isolated to serving the plant steam and generation facilities. The primary 13. 2 kV system

consists of 120 miles of lines, with approximately 29% consisting of overhead line and 71% of

underground cable.

M1ENGINEERING




Executive Summary

DESIGN CRITERIA

The following design criteria was used in evaluation of the performance of the electric system.

Criterion # 1 Provide " N- 1" ( single contingency) level of reliability for all transmission, substation, and distribution facilities.

Criterion # 2 Provide ANSI " Class A" voltage service to all customers, under normal or

emergency conditions.

Criterion # 3 Do not exceed thermal limitations of facilities on the electric system, under

normal or emergency conditions.

EXISTING SYSTEM DEFICIENCIES

Due to continued system growth and aging infrastructure, the following deficiencies have beenidentified:

With an intact system experiencing load growth projected over the next 20 years, lowvoltage and circuit overload conditions exist on distribution circuits fed out of the North

Side Substation.

With an intact system under projected load conditions, the North Side substation

transformer becomes overloaded.

With N- 1 contingencies affecting the system under projected load growth, deficienciesidentified under intact system voltage and overload conditions become worse.

Under future load conditions and with the loss of one of the substation transformers or

13. 2 kV switchgear buses, significant low voltage and overload conditions exist on several

distribution feeder circuits when back -fed on the distribution system. Conditions of most

concern are when back -feeding the northwest area of the system from the Center Streetor Power Plant distribution feeders.

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Neter Ulm Public Utilities

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Executive Summary

With the loss of the East Side to Center Street 69 kV transmission line under existing load

conditions, the operation of fuel oil burning Generators # 5 & # 7 is required for power

supply backup to the Center Street and South Side substations. When applying futureprojected loading to the system, Generator # 4 is also required for power supply backup.

With the loss of the Center Street to South Side 69 kV transmission line under projected

load growth, the North Side substation transformer is overloaded, and significant voltage

drop conditions exist on the distribution feeders.

With the loss of the Center Street substation 69 kV bus under projected load growth,

existing backup generation capacity is insufficient to provide power supply for the entiresystem.

Areas of the existing East Side 69 kV transmission line have significant damage due towoodpeckers.

The Center Street and South Side substations have oil -insulated 69 kV power circuit

breakers in service that are approaching the end of their usable life.

The Generator # 7 13. 2- 69 kV step-up tie transformer at the Center Street substation is

approaching the end of its usable life.

The North Side, South Side and Power Plant substations utilize electromechanical style

relays original to the initial construction of the substations.

Existing 13. 2 kV and 2. 4 kV metalclad switchgear lineups at the Center Street and PowerPlant substations are original and will need replacement in the next 20 years.

The 13. 2- 2. 4 kV tie transformers located in the Power Plant substation are approachingthe end of their usable lives.

A 1 mile segment of the North Side to Center Street transmission line is estimated to be

over 50 years old, and will need replacement due to age and condition of the facilities in

the next 20 years.

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Executive Summary

CAPITAL IMPROVEMENTS PLAN SUMMARY

The following is a summary of the recommended improvement projects necessary, and the

associated estimate of costs to resolve system deficiencies. The estimates do not include ongoingoperations, repairs and replacements to the primary and secondary distribution system. The

estimates are based on 2nd quarter 2018 contractor and materials pricing and include costs for

contingencies and engineering.

SUMMARY OF 20 YEAR CAPITAL IMPROVEMENTS PLAN COST ESTIMATE

1 A North Side West Feeder Improvements $ 690, 000

B West Side Substation Construction0- 1 MW Growth

5, 990, 0002019- 2020

C Xcel Sub to West Side Sub Interconnection 1, 510, 000

PHASE 1 SUBTOTAL 8,190,000

2 A Transmission Reconstruction — 0. 9 Miles 1, 100, 000

East Side Woodpecker Damage2019- 2020

B Transmission Construction — 5. 5 Miles 2, 910, 000

East Side to South Side Sub


3 Transmission Construction — 1. 4 Miles 1, 060, 0002020- 2024

West Side Sub to North Side Sub

PHASE 3 SUBTOTAL 1, 060,000

4 A Center Street Sub Upgrades 2024- 2029 2, 030, 000

B Power Plant Sub Upgrades 2024- 2029 2, 080, 000

C South Side Sub Upgrades 2030- 2039 1, 550, 000

D Transmission Reconstruction — 1. 0 Miles2034- 2039

610, 000

North Side Sub to Center Street Sub


TOTAL ESTIMATED COST — 20 YEAR CIP $ 19,530,000

MVIElectrical System Study & Capital Improvements Plan


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Introduction

1. INTRODUCTION:

New Ulm Public Utilities ( NUPU), of New Ulm, Minnesota owns and operates an electric

system that provides electric service to the businesses and citizens of New Ulm. DGR

Engineering ( DGR) was commissioned to perform an evaluation of NUPU' s electric system

and develop a Capital Improvements Plan ( CIP).

1. 1. Scope: It has been approximately ten ( 10) years since a system -wide assessmenthas been completed for NUPU' s electric system. Since then, several changes have

occurred on the system and an updated study is necessary to account for these

changes in NUPU' s planning process. Analysis of NUPU' s electric system in this studyincludes the 69 kV transmission, 13. 2 kV distribution, generation and substation

facilities owned and operated by NUPU. Also included in this study is a high- level

assessment of the 69 kV transmission facilities surrounding New Ulm and the long-

term supply of transmission supply to NUPU. The development of this report consisted

of the following general process.

1. 1. 1. Data collection and model development: An on- site visit was

conducted to visually inspect NUPU' s facilities and operations. A

meeting with staff was held to obtain information regarding the day to

day operations of the electric system. Concerns of the personnel in

charge of maintaining the high level of service NUPU is accustomed to

providing its customers were documented and considered. Diagrams,

system and consumer load data, GIS and other information regardingelectrical equipment and layout of the system were obtained from

NUPU staff to assist in developing a software model of the electricdistribution system.

1. 1. 2. Load flow — existing & projected: With system peak and consumer

demand data collected, load was allocated across the model to

simulate NUPU' s electric system and its ability to distribute powerthroughout its service area in an efficient manner at load levels

recorded in the last 10 years. Based on a combination of the 10 -year

M1Electrical System Study & Capital Improvements Plan


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Introduction

load growth and staff input, a future load projection was developed to

assess the system' s performance over the next 20 years.

1. 1. 3. System analysis: The electric system was analyzed as it exists today

under both existing historical peak and future projected demand

levels. Contingency analysis was conducted to assess the system' s

flexibility and redundancy, and deficiencies in voltage and capacitywere identified. The general age and condition of distribution,

substation and transmission facilities was documented and assessed.

1. 1. 4. CIP Development: Capital improvement projects were identified and

tested using the voltage and capacity design criteria to correct thedeficiencies identified. This report outlines the capital improvements

projects recommended to eliminate deficiencies identified under

existing and future system conditions. The CIP covers a twenty-year

period and provides budgetary cost estimates for fiscal planning.

DGR would like to acknowledge the contributions of the NUPU staff, who were critical in

providing the necessary data, access and input regarding the day to day operations of theelectric system to assist in development of this report.



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Load Growth Projections

2. LOAD GROWTH PROJECTIONS:

2. 1. General: The projected system load and the desired level of service dictate the level

of capital expenditures required to provide adequate service to all customers. This

section discusses the historical and projected system loading requirements.

2.2. System Demand Requirements: Table 1 lists the historical and projected peak

power demands for NUPU' s electric system. This historical load data was furnished

by NUPU staff.

Based on the demand and energy data received, the annual summer and winter peakdemand generally remained steady with an average summer peak of 44.9 MW and

average winter peak of 29.7 MW. NUPU usually reaches its peak demand during thesummer months of July or August, which is generally due to the large air conditioningloads of residents and businesses in the city. The peak winter demand was seen inNovember of 2016, with a peak demand of 33. 3 MW. Overall, the winter load levels

are consistent with little growth. Since the summer peak is much greater and is

expected to continue to be in the future, system planning is based on the summerload information.

The 10 year peak was recorded in the summer of 2011 at 48. 5 MW. Most recently in

July of 2017, a peak of 45. 9 MW was recorded. On average the annual summerdemand did not increase greatly, with an average annual summer demand growth ofonly 0. 1%. However, if the 2011 peak is compared to the 10 year average peak of

44.9 MW, a demand increase of 8% is possible in a given year depending on the

summer temperatures. A proper load forecast must consider the possibility of theaddition of new consumers and the system should be designed with flexibility tohandle the growth as necessary.

In conjunction with NUPU staff, areas of New Ulm were identified as prospective

growth areas based on city zoning and interest expressed by commercial entitieswishing to expand or move their operations. Through meetings and several follow- upconversations with NUPU staff regarding locations and size of likely growthdevelopments, a load growth rate of 1. 5% was established to forecast load over the

20 -year period of this study. At an annual growth rate of 1. 5%, the peak demand is

estimated to add approximately 17 MW, from a 2017 peak of 45. 8 MW to a peak of62. 9 kW in 2038. The historical and projected system demand requirements are

shown in Table 1 and illustrated in Figure 1.


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HISTORICAL


TABLE 1

HISTORIC LOAD DATA AND PROJECTIONS


Summer Peak Winter Peak

Year Demand ( kW) Donand (kW)

2007 46, 128 30, 025

2008 45, 579 301000

2009 42,455 29,600

2010 45,651 30, 425

2011 48, 533 29, 580

2012 45,206 28, 210

2013 45,737 29, 600

2014 42, 166 29, 120

2015 42,320 27,765

2016 44,589 33, 350

2017 45,863 29,062

Summer ilk

Year Demand ( kW)

PROJECTIONS

Winter Peak

Demand ( kW) 2018 46,557 29,207

2019 47, 261 29,353

2020 47,976 29,500

2021 48,702 29,648

2022 49,439 29,796

2023

2024

50, 186

50, 946

29,945

30,095

2025 51, 716 30, 245

2026 52, 499 30, 396

2027 53, 293 30, 548

2028 54,099 30, 701

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New Ulm Pudic Utilities

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PROJECTIONS

CONTINUED)

2029 54,917 30, 854

2030 55, 748 31, 009

2031 56, 591 31, 164

2032 57, 448 31, 320

2033 58, 317 31, 476

2034 59, 199 31, 634

2035 60,094 31, 792

2036 61, 003 31, 951

2037 61, 926 32, 110

2038 62, 863 32, 271

Figure 4 of Appendix A shows a load growth map that highlights areas of New Ulm

where growth is expected. The following is a basic breakout of how load growth wasclassified and distributed across the system model:

New Large Industrial Load 5 MW

Existing Industrial Growth 5 MW

New Commercial Load 4 MW

Existing Commercial Growth 700 kW

New Residential Load 1 MW

General System Growth 825 kW

System Losses 600 kW

Total Growth 17. 125 MW



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FIGURE 1

SYSTEM DEMAND REQUIREMENTS

New Ulm Public Utilities Commission

2007 2009 2011 2013 2015 2017 2019 2021 2023 2025 2027 2029 2031 2033 2035 2037

YEAR

Historical Winter Demand— Q— Historical Summer Demand

Projected Winter Demand — Projected Summer Demand

70,000

65,000

60.000

55,000 3Y

50,000 0Zd

45,000 W0

40,000

a

35,000

30,000

25,000

20,000

Note that if the load were to grow at a more aggressive rate than this projection,

improvements identified in the study may need to be completed sooner, or additionalprojects over and above those identified in this study may be required.

2. 3. System Energy Requirements and Losses: Table 2 of the following page lists

the historical energy purchases, sales, losses, load factor, and projected energy

purchases for NUPU' s electric system. Energy purchase projections are based on aconstant 52% load factor, which is defined as the ratio of the average energy ( kWh)

to peak demand ( kW) calculated over a 1 - hour period. Historical energy data wasobtained from NUPU.




HISTORICAL

PROJECTIONS

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TABLE 2

HISTORIC ENERGY DATA AND PROJECTIONS


EnergyPurchased

Year ( MWh)

Energy EnergySold Generated

MWh) ( MWh)

Losses

Annual

LoadFactor

2007 211, 323

2029

204,016 3, 656 5. 1% 53. 2%

2008 207, 191

218, 917

199,905

258, 230

955 4.0% 52. 1%

2009 169 717 188, 392

266, 102

27,090 4. 3% 52. 9%

2010 205, 353

232, 468

197, 443

274, 214

4,472 5. 9% 52. 5%

2011 207, 125

239, 554

198 1 385 5, 854 6. 9% 50. 1%

2012 198,261 188 281 6, 693 8. 1% 51. 8%

2013 195, 165 187, 057 4,814 6. 5% 49. 9%

2014 197, 772 190 663 2 675 4.9% 54.3%

2015 198, 388 191, 207 3 607 5. 3% 54. 5%

2016 201, 276 193, 930 6, 137 6. 5%

2017 207, 114 197, 065 2, 901 6. 2%

EnergyPurchases

Year ( MWh)

EnergyPurchases

Year, ( MWh)

2018 212,441 2029 250,591

2019 215, 655 2030 254, 382

2020 218, 917 2031 258, 230

2021 222, 229 2032 262, 136

2022 225, 591 2033 266, 102

2023 229, 003 2034 270, 127

2024 232, 468 2035 274, 214

2025 235, 984 2036 278, 362

2026 239, 554 2037 282, 573

2027 243, 178 2038 286, 847

2028 246, 857



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Figure 2 illustrates graphically the energy projections shown in Table 2.

FIGURE 2

SYSTEM ENERGY REQUIREMENTS

New Ulm Public Utilities Commission

2007 2009 2011 2013 2015 2017 2019 2021 2023 2025 2027 2029 2031 2033 2035 2037

Year

Q- Historical Energy Purchases - 4 Projected Energy Purchases

300,000

290,000

280,000

270,000

260,000 3250,000

240,000

230,000

220,000

210,000 j200,000 a190,000 tko

180,000 C170,000

160,000

150,000

140,000

130,000

120,000

110,000

100,000




Design Criteria

3. DESIGN CRITERIA:

3. 1. General: The criterion for proper design of electric utility systems is described in thefollowing paragraphs. All criteria are important, and all efforts were made to satisfythem in the design of the system plan.

3. 2. System Reliability: In general, NUPU should adopt a policy to maintain " N- 1" or

single contingency" design, on all transmission, substation, and distribution facilities. Single contingency" design is defined as the ability to operate the system at peak

load with the loss of any single major system component. Electric consumers havecome to expect that electric service be available at all times, except for minor

weather- related outages. We feel that it is important that the electric system be able

to survive the loss of any one piece of equipment or line section, and still be able to

carry peak load while providing Class A service.

3. 3. Voltage Levels: Voltage levels at the consumer's premises should be maintained

within ANSI limits for Class A during normal or contingency switching conditions. ANSIvoltage limits are as follows:

Maximum Voltage 126 volts

Minimum Voltage 110 volts

Maximum Daily Voltage Swing 8 volts

These values are the maximum and minimum voltages a customer could experience

at utilization equipment, and still be in compliance with ANSI standards. In addition,

no customer should experience a difference ( swing) of more than 8 volts in any 24

hour period without violating ANSI standards. Voltage drop is a natural occurrence

on an electric system. Voltage drop across the various electrical equipment must be

calculated and included in the planning process. In order for an electric system tomaintain sufficient voltage levels from the substation source to the end- user, the

following accumulation of voltage drop at different levels of the system are assumedfor an overall sum of 16 V of drop as allowed in the design criteria:

Primary Circuits 3. 5 V

Distribution Transformers 3. 5 V

Secondaries 3. 5 V

Services 1. 5 V

Customer Wiring 4. 0 V



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SUI

Design Criteria

The voltage drop profile in Figure 3 illustrates the allowable voltage drop componentsacross a distribution system, from the start of the primary distribution feed from the

substation to the end- user. The specific portion of the assigned voltage drop that iscontrollable directly by a utility is that portion assigned to primary circuits. Planningis done to ensure that voltage drop on primary circuits does not exceed 3. 5 volts,

under the assumption that the other components of drop will be present.

FIGURE 3

VOLTAGE DROP PROFILE CRITERIA

12!

124

127

12C

3,

Ii

J, J

PfBMlAR'+' _i___$

ECONOARY SERVICE _ HOUSE --'_-- !

VOLTAGE DROP ALLOCATIONS FOR ACCEPTABLE SERVICE ( PEAK LOW)

VOLTAGE DROP ALLOCATIONS ( UGHT LOAD)

126

121

122

120

ne

118i

106

106

104

102

0 1=1ENGINEERING

3. 4. Capacity: Along with maintaining voltage levels, consideration of equipment thermalcapacity was evaluated. The capacity criterion of this study requires that all major

electric facilities, including substation transformers, switchgear, distribution lines andassociated equipment be kept within published thermal limits at all times, during bothnormal and emergency operations, to prevent overload and subsequent thermalbreakdown.




Design Criteria

3. 5. Flexibility and Expandability: Electric system improvements should be designed

to provide efficient power delivery with variable circuit configurations to serve existingand future consumers. This is accomplished by designing multiple tie and switching

points between distribution circuits designed in loop configurations for the ability toback -feed areas of the system if needed. A flexible system will allow the ability to

transfer loads from circuit to circuit and provide options for optimizing the system asload requirements change.

The system should also be designed to be expandable, so new load can be added to

it without major disruption to the existing system. Sufficient capacity must be

available in substations and lines to handle the addition of a reasonably large loadwithout scrambling to provide facilities for it. This does not mean, however, that thesystem should be overbuilt, but it does mean that additional capacity should exist to

handle new loads. A major function of this study is to serve as a road map for the

utility to follow if and when definite load growth is identified, and to be prepared toact efficiently and quickly to accommodate new consumers, large or small.

MalElectrical System Study & Capital Improvements Plan



Existing System Analysis

4. EXISTING SYSTEM ANALYSIS:

4. 1. General: Analysis of the existing system consisted of site visits, review of historical

records, and discussion with staff regarding the day-to-day operations of the system.

Meetings were held with NUPU personnel to receive their input covering various pastconstruction methods and procedures utilized to operate and maintain the electrical

facilities. The study work included a review of NUPU' s transmission, substation,

generation capacity and distribution components of the electric system as described

in this section. Figure 5 in Appendix A illustrate NUPU' s existing electric system.

4.2. Power Supply Arrangement: NUPU purchases wholesale power through a long- term agreement with Heartland Consumers Power District ( HCPD) for its base load.

NUPU supplements its wholesale power supply by purchasing energy on the

Midcontinent Independent System Operator ( MISO) Day -Ahead Market, and with alimited amount of local generation.

4.3. Transmission: NUPU owns and operates 6. 7 miles of 69 kV transmission lines that

connect the North Side, Center Street and South Side substations to the regional grid.

NUPU receives transmission service at 69 kV through substation and transmission

facilities owned and operated by Xcel Energy ( Xcel). NUPU is fed by two ( 2) 69 kV

radial transmission taps, both connecting to the north area of NUPU's transmissionnetwork. A source from the west originates out of Xcel' s West New Ulm substation

and connects to NUPU' s network via a 1 -way switch structure located on a 115/ 69 kV

double circuit transmission line at N. Broadway St. & 22nd St. The 0. 8 mile line section

terminates into the west bay of the North Side substation. A source from the east

originates out of Xcel' s Ft. Ridgely substation approximately 1. 7 miles northeast ofNew Ulm and taps the North Side — Center Street line through a 3 -way switchstructure located just west of the Minnesota River, east of the 19th N. St. & Front St.

intersection.

While NUPU has two ( 2) transmission sources, since they are both connected at the

north end of town, the Center Street and South Side substations are radially fed. In

the event the radial 69 kV line segment from the Xcel Ft. Ridgely tap to the Center

Street substation is lost, NUPU must rely on generation to feed much of the town.

The bulk of NUPU' s transmission lines were constructed in the 1980' s and 1990' s and

consist of wood pole structures with porcelain horizontal line post insulators

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supporting 556 ACSR or 266 ACSR phase conductor with a steel shield wire for

lightning protection. The staff of NUPU discussed of porcelain post insulators breaking

and requiring occasional replacement, however it does not appear to be a widespread

concern. Approximately 1 mile of older line exists in a segment between the NorthSide and Center Street substations that was constructed in the late 1960' s,

approximately the same time the Center Street substation was constructed. The lineconsists of wood poles with " wishbone" style crossarms and suspension insulators

supporting 266 ACSR phase conductors with a steel shield wire.

Over the years, woodpeckers have caused significant damage to the wood structures

on portions of NUPU' s 69 kV transmission system, particularly on lines in the heavilywooded areas near the river. The area of the system most affected is a 0. 8 mile

segment of the East Line, which is part of the East Line connecting NUPU to Xcel' s Ft.

Ridgely substation. The line segment crosses the Minnesota River through and oldrailroad bed. Recently an assessment was completed on the damaged structures, and

the structural integrity of the poles was determined to be a serious concern. It wasrecommended that a section of the East Line be rebuilt with steel pole construction

to eliminate vulnerability to woodpeckers. NUPU is currently in the design phase of

this transmission project.

4.4. Substations: NUPU owns and operates three ( 3) 69 kV - 13. 2 kV substations and

one ( 1) 13. 2 kV — 2. 4 kV substation that serve NUPU' s distribution load. Figure 7 of

Appendix B is a one -line diagram illustrating the configuration of the existing electricsystem.

4.4. 1. North Side Substation: The North Side substation consists of two ( 2)

69 kV deadend terminals constructed of Al. bus supported with tubular

steel structures on concrete foundations. The substation currently hasthree ( 3) 69 kV SF6 gas insulated circuit breakers with provisions for

installation of a fourth breaker. Currently, there is one ( 1) 69- 13. 2 kV

12/ 22.4 MVA rated power transformer equipped with a load tapchanger for voltage regulation. A spare bay with concrete pad

foundation is located next to the existing unit for installation of asecond transformer in the future. The transformer supplies an indoor

metalclad switchgear lineup of one ( 1) main breaker and five ( 5)

feeder breakers in a nearby control building. The control building



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appears to have been designed with space provisions for the addition

of another metalclad switchgear. The switchgear breakers are

equipped with electronic SEL -351A distribution relays for overcurrent

protection of the switchgear and circuits. Electromechanical relays are

relied on for instantaneous differential protection of the switchgear

bus. Within the control building is a 69 kV control panel lineup housingelectromechanical relays utilized for power transformer and 69 kV bus

and line protection. There is an electronic SEL -321 distance relay forcontrol of one ( 1) 69 kV breaker. The control panels include space for

additional 69 kV relaying equipment. Generally, the North Side

substation equipment is original and was installed with construction of

the substation in 1990, with the exception of the SEL -351 distribution

relays and the SEL -321 69 kV line relay.

The North Side substation is connected to two ( 2) transmission lines

and can be sourced from either of Xcel's West New Ulm or Ft. Ridgelysubstations. The substation is also able to be back -fed through the

distribution system via a dedicated mainline express circuit connecting

to the Center Street substation switchgear. This allows for some

flexibility in back -feeding the distribution system at existing peak loadlevels.

4.4. 2. Center Street Substation: The Center Street substation consists of two

2) deadend 69 kV terminals constructed of Al. bus and bare overhead

conductor, supported with a steel lattice box structure on concrete

foundations. The substation currently has three ( 3) 69 kV oil -insulatedcircuit breakers manufactured in the 1970's, and one ( 1) SF6 gas -

insulated breaker similar to that installed at the North Side substation.

The oil -insulated breakers are approaching the end of their useablelife, and replacement of these breakers is recommended within the

next 20 years.

There are two ( 2) 69- 13. 2 kV power transformers with load tapchangers in the substation. The main power transformer is rated for

33. 6/ 56 MVA and feeds a 13. 2 kV outdoor metalclad switchgear lineup.

The switchgear consists of a main breaker supplying a main bus



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connected to three (3) tie breakers that feed two (2) feeder switchgear

buses and a tie circuit. The tie circuit connects to the Power Plant

substation 13. 2 kV switchgear. The 13. 2 kV switchgear buses are each

tied to a different substation via mainline express feeders, dedicated

for back -feed purposes. The outdoor switchgear breakers are

equipped with electronic SEL -351 distribution relays for time

overcurrent protection of the distribution circuits, housed in a control

panel lineup located in a control building. The control panel alsohouses electronic SEL -351 and SEL -387 relays for overcurrent

protection of the 69 kV power transformer. SEL -501 overcurrent relays

are configured to operate as bus differential protection for the 69 kV

and 13. 2 kV switchgear buses. Due to the basic nature of the SEL -501

overcurrent relay, it is generally not utilized for bus differential

protection, but is usually used as a backup time-overcurrent relay.

A 5, 200 WAR capacitor bank is fed out of one ( 1) feeder switchgear

breaker. The capacitor bank consists of two ( 2) steps of 2, 700 WAR

and is operated and protected with an electronic SEL -487V relay

housed in a cabinet attached to the outdoor capacitor bank enclosure.

The capacitor bank is utilized to help maintain a system power of 98%

or better to meet Xcel Energy's power quality requirements. It isstepped in and out on a regular basis as needed.

The second power transformer at the Center Street substation serves

as a 13. 2- 69 kV generator step- up ( GSU) tie for Generator # 7. The

transformer is rated at 12/ 22.4 MVA and was manufactured in 1968

and installed at that same time, when original construction of the

Center Street substation was completed. Due to its age, replacement

is likely to be necessary in the next 20 years.

4.4.3. Power Plant Substation: The Power Plant substation consists of

medium voltage switchgear that feed additional 13. 2 kV distribution

circuits, interconnects 13. 2 kV generation assets, and supplies

2. 4 kV service to the steam and generation facilities. There are two (2)

13. 2- 2.4 kV 7. 5/ 8.4 MVA rated power transformers at the power plant

location. One transformer serves as a generator step-up ( GSU) tie for



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Generator # 6 and its feed to the 13. 2 kV switchgear bus # 1. The other

serves as the station power transformer for the 2. 4 kV switchgear

located in the plant. The transformers are of similar age and condition,

both installed approximately during 1960's upgrades completed at the

substation. The transformers will likely need replacement in the next

20 years, as they have been in use for over 50 years.

There are three ( 3) 13. 2 kV metalclad switchgear buses located in the

Power Plant building. Bus # 1 feeds circuits on the primary distribution

system, ties to Generators # 4 and # 6, ties to 2.4 kV switchgear via a

step down transformer, and ties to 13. 2 kV switchgear buses # 2 and

3. Bus # 2 feeds two ( 2) distribution circuits and ties to the Center

Street substation switchgear. Buses # 1 and # 2 are connected in the

same switchgear lineup and appear to have been in use since the1960' s. The protective relays for the switchgear breakers are

electromechanical and have been fitted with electronic display meters. Switchgear bus # 3 consists of three ( 3) breakers utilized for tying bus

1, the 2. 4 kV switchgear bus tie transformer and the Center Street

switchgear bus during back -feed conditions. Bus # 3 switchgear was a

recent addition to the Power Plant within the last 10 years. Bus # 3 has

a fused bay that feeds the 2, 500 kVA tie 13. 2- 2. 4 kV tie transformer.

The 2. 4 kV switchgear is utilized for supplying station power to theplant steam and generation facilities, such as pumps, boilers and other

auxiliary power and controls. The 2.4 kV switchgear bus # 2 consists

of old air breakers and has been in use for over 50 years. It serves as

a switching point between the 13. 2- 2.4 kV tie transformer and the2. 4 kV bus # 3 that distributes load to the plant facilities. Buses # 3 and

4 are relatively new switchgear lineups recently added to the plant

for the interconnection of standby emergency generators and

additional auxiliary equipment.

4.4.4. South Side Substation: The South Side substation consists of two ( 2)

69 kV deadend terminals constructed of Al. bus supported with tubular

steel structures on concrete foundations. The substation currently has

a total of three ( 3) 69 kV circuit breakers, with provisions for the

MWIElectrical System Study & Capital Improvements Plan

New Ulm Public utilities

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installation of a fourth breaker. Two ( 2) of the circuit breakers are oil -

insulated and were installed during original construction of thesubstation in the 1979- 1980 timeframe. The third is an SF6 gas -

insulated breaker installed recently with additions of a transformer andswitchgear. There are two ( 2) 69- 13. 2 kV power transformers

installed, rated for 12/ 22. 4 MVA and 15/ 28 MVA respectively, both

equipped with LTCB for voltage regulation. Each transformer supplies

an indoor metalclad switchgear lineup through a main breaker located

in a control building. The switchgear lineup fed by the 22.4 MVA unit

originally installed at the substation is protected with

electromechanical relays for overcurrent protection of the distribution

circuits. The switchgear lineup fed by the 28 MVA transformer isequipped with electronic SEL -351 distribution relays for overcurrent

protection of the switchgear and circuits. A 69 kV control panel lineuphouses electromechanical relays for differential and overcurrent

protection of the original transformer, and an electronic relays for

differential and overcurrent protection of the newer transformer,

69 kV substation bus and 69 kV transmission line.

The South Side substation is connected to one ( 1) transmission line

fed radially from the Center Street substation. The substation relies onties through the distribution system feeder circuits and a dedicated

mainline express circuit connecting to the Center Street substation

switchgear for back -feeding in the event of a transmission or 69 kV

bus outage. This allows for some flexibility in back -feeding the

distribution system at existing peak load levels.

4.5. Distribution: The existing primary electric distribution system is operated at13. 2 kV. It includes nineteen ( 19) feeder circuits and three ( 3) express feeders that

supply approximately 34 miles of overhead and 86 miles of underground distribution

lines. Figure 5 in Appendix A is a map of the existing distribution system and

Figure 7 in Appendix B is a one -line of the existing system illustrating the layout andconfiguration of areas served across the distribution system.

4. 5. 1. Overhead: The physical condition of the existing 13. 2 kV distribution

system is overall very good, as NUPU has historically replaced aging

MMIElectrical System Study & Capital Improvements Plan




overhead infrastructure with underground circuitry. The overhead lines

remaining in service are well built of typical modern construction

methods, and NUPU does not report many issues with reliability. Theoverhead lines consist primarily of aluminum conductor -steel

reinforced ( ACSR) type conductor ranging from # 4 AWG — 556 kcmil

in size. The wood poles on the system are tested on a 10 year cycle,

and structures are replaced as needed.

4.5. 2. Underground: NUPU' s underground facilities consist mostly of 500

kcmil CU and 4/ 0 AWG AL three-phase mainline trunk circuits serving

as the primary backbone of the distribution system for switching and

transferring load. Three- phase and single-phase sub -loops constructedof 1/ 0 and # 2 AWG AL cable are sectionalized from the mainline for

supply of primary sectionalizing cabinets and service transformers. Thesubstations are tied together on the distribution system with high-

capacity express feeders constructed of parallel 500 kcmil CUconductors in sand encased ductbank. Most of the underground cable

is installed in PVC conduit. NUPU utilizes oil, SF6 gas, or solid -dielectric

insulated padmount switchgear with vacuum fault interrupters ( VFI)

for the sectionalizing of underground circuits. Deadbreak elbow

terminations rated for 600 A are utilized for the switch connections to

mainline circuits which allows for flexible loading of the mainline

circuits during various switch configurations. For the subloop circuit

connections to the switch VFIs, 200 A elbows are generally utilized.

NUPU is presently satisfied with the performance of the switchgearinstalled on the system. All new distribution circuits are of underground

construction, and NUPU has a general goal of a complete underground

system.

4.6. Generation: NUPU has a total generation capacity of approximately 73 MW locatedat the Center Street and Power Plant substation locations.

4.6. 1. Center Street Substation: At the Center Street substation are

Generators # 5 and # 7. These are fuel oil powered jet turbines rated

for 25. 4 MW and 28. 3 MW respectively and generate at 13. 2 kV. Generator # 5 is connected to the substation 13. 2 kV switchgear bus,

M1Electrical System Study & Capital Improvements plan

New Ulm public Utilities

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and Generator # 7 is connected to the 69 kV bus through a 69- 13. 2 kV

tie transformer. They are black -start capable and could serve as

relatively quick backup in the event of an outage on the radial 69 kVtransmission line feeding the Center Street substation. Generators # 5

and # 7 are available for backup, but are expensive to operate as a

long- term power supply due to their expensive fuel source.

4. 6. 2. Power Plant Substation: At the Power Plant substation, Generators # 4

and # 6 are connected to 13. 2 kV switchgear bus # 1. Generator # 6 is

a 6 MW rated natural gas powered steam turbine generator that

generates at 2.4 kV, and feeds a 13. 2- 2. 4 kV tie transformer for

connection to the 13. 2 kV switchgear. Generator # 4 is a 15 MW rated

natural gas powered steam turbine generator that generates at

13. 2 kV and connects directly to the Power Plant 13. 2 kV switchgear. NUPU regularly markets steam production to large industrial

consumers through the steam generators located at the Power Plant.

These natural gas powered generators are less expensive to operate

as a power supply in the event of a long- term outage to thetransmission system. NUPU also operates two ( 2) 500 kW back

pressure turbines that generate power from the excess steam

produced by the steam engine turbines. The power generated fromthe steam engines supplements the electric system demand and

accounts for most of the energy generated by NUPU on an annualbasis.

4.7. Power Factor: NUPU has three ( 3) main capacitor bank installations totaling 8, 550

WAR on the electric system utilized for maintaining power factor to meet Xcel

Energy's 98% requirement. A 1, 350 WAR bank with three ( 3) steps of 450 WAR is

located at the Kraft industrial facility and an 1, 800 WAR bank with four ( 4) steps of300, 600, 450 and 450 WAR is located at the 3M industrial facility. These capacitorbanks near the large industrial facilities are switched in and out automatically tomaintain power factor and voltage levels. At the substation level, a 5, 400 WAR bank

installation consisting of two (2) steps of 2,400 WAR are installed at the Center Streetsubstation. The bank is connected through a switchgear breaker to the 13. 2 kV bus,

and is controlled as necessary to help maintain the overall system power factor. Additionally, various small capacitor banks are located on the overhead portions ofthe distribution system that were installed initially for voltage support, and are

generally removed from service when conversion projects to underground arecompleted.



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4.8. Voltage and Capacity Analysis:

4.8. 1. Load Flow Model: A load flow analysis of the distribution system was

performed using the Milsoft WindMil® computer modeling program.

This program is a commercial product that can perform load flow,

short-circuit, and other analysis of a modeled electrical system. The

voltage level and capacity constraints of the system were analyzed

under existing historical and projected peak loading conditions. Thismodel was developed based on the GIS data and circuit diagrams, and

switch drawings provided by NUPU. Load information collected foreach circuit and for large power consumers was collected from NUPU

staff and incorporated into the model. We feel the model provides an

accurate tool for analyzing various " N- 1" contingency scenarios suchas the loss of specific pieces of equipment, various switching

conditions, and the effects of load growth on the system. NUPU

currently utilizes a GIS system model for electric system mapping andto document information on electrical facilities installed on their,

system. GIS data can be transferred through various file formats and

is an efficient medium for updating and utilizing the load flow model

developed for the purposes of this study, and we encourage NUPU' sstaff to utilize the load flow model as needed for analytical and

planning purposes.

4.8.2. Summary of Analysis: Our analysis indicates that NUPU has a well-

maintained primary distribution system with sufficient flexibility and

redundancy for the load levels experienced to -date. However, as load

increases as projected over the next 20 years, low voltage and capacityconcerns are identified.

Since the bulk of NUPU' s load growth is expected in areas located at

the outer northwest area of the system, it becomes difficult and

expensive to add enough primary distribution infrastructure from the

centrally located Power Plant and Center Street substations to deliverpower to the outer areas of the system without significant voltage and

capacity issues. When looking at loads on the existing system at the



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end of 20 years with approximately 17 MW of growth, the North Side

power transformer and its West Circuit are overloaded significantly as

currently configured, in an intact, normal system condition. Based onour load flow model, the northwest industrial area of the town can

withstand approximately 1- 2 MW of growth before significant voltage

drop occurs on the North Side substations West Feeder circuit. When

conducting contingency analysis with load growth factored, significant

voltage and capacity deficiencies are more widespread on severalareas of the system. Table 3 summarizes the capacities of each

substation during normal intact system operation under existing andprojected peak load conditions.

TABLE 3

SUBSTATION CAPACITIES

MM, dmurrl ftftbft PrrojecUd

SubsWon iransslorm®r k 20 Year PeakCam Und Lwd

As the table shows, the Center Street and South Side substations have

sufficient capacity at existing and projected loads. The North Side

substation maximum capacity is sufficient at existing load levels, however when load is added in the northwest area of the system the

existing transformer is overloaded.

While a transformer can be added in the North Side substation to

address the lack of capacity, there would be significant distributioncircuit additions required to connect the industrial loads of the

northwest area to the new transformer. Overloading of the North Side

substation transformation and circuit capacity becomes worse with the



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North Side 22.4 MVA 12. 1 MVA 23. 9 MVA

Center Street

feeds Power Plant) 56.0 MVA 18. 1 MVA 22. 0 MVA

South Side 50.4 MVA 17. 4 MVA 20. 6 MVA

Total 128.8 MVA 45. 6 MVA 66. 5 MVA

As the table shows, the Center Street and South Side substations have

sufficient capacity at existing and projected loads. The North Side

substation maximum capacity is sufficient at existing load levels, however when load is added in the northwest area of the system the

existing transformer is overloaded.

While a transformer can be added in the North Side substation to

address the lack of capacity, there would be significant distributioncircuit additions required to connect the industrial loads of the

northwest area to the new transformer. Overloading of the North Side

substation transformation and circuit capacity becomes worse with the



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loss of a major piece of equipment as identified in the contingency

analysis of this study.

With the loss of a single piece of major equipment such as the Center

Street power transformer or 69 kV transmission line to the South Side

substation, stress is placed on the North Side substation and feeder

circuitry when backing up the system. Similarly, if the North Sidetransformer or switchgear bus is lost, Center Street feeders are

required to backup the facilities in the northwest area of the system

from the Center Street location, causing significant voltage concerns

on the long feeder circuits.

Additional options were developed for the addition of capacity for thenorthwest portion of the system and to determine if the addition of a

new substation would be more effective. Based on our assessment,

the addition of a substation in that area of the system, when

coordinated with additional transmission improvements, would

improve the overall systems reliability and efficiency in the future.

The existing transmission infrastructure is operated in a radial fashion,

with a long segment of line radially feeding both the Center Street and

South Side substations. The transmission lines are mostly in goodcondition, except for a portion of the East Side 69 kV transmission line

that has been damaged by woodpeckers that is currently scheduled

for reconstruction. NUPU currently has sufficient generation capacity

to handle peak load conditions during a brief transmission outage.

However, a long- term outage due to the failure or maintenance of a

transmission line, power transformer or 69 kV bus would be veryexpensive due to the fuel costs associated with Generators # 5 and # 7.

If a transformer fails, replacement of the transformer can take 1- 2

years when factoring the design, bidding, manufacturing, installation

and commissioning of a new transformer. When a 69 kV transmission

line segment or substation bus is damaged by weather, a mechanical

failure or by accident, it may take several days, weeks, or even months



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Existing System .Analysis

to procure a contractor and the materials necessary to reconstruct the

facilities depending on the situation.

While the transmission system has two ( 2) sources out of Xcel' s West

New Ulm and Ft. Ridgely substations, NUPU does not have control ofthe West New Ulm breaker terminal. It taps an Xcel 115/ 69 kV double

circuit line fed out of the substation with a 1 -way switch. For a

community the size of New Ulm with the heavy industrial andcommercial loads present on the system, it is our opinion that a closed

loop transmission system should be pursued as part of a long range

plan, if possible. Infrastructure planning should include provisions forthis to be completed through a series of transmission and substation

improvements. Overall, NUPU' s existing 69 kV substation facilities aredesigned in a breaker -in / breaker -out fashion that allows for a looped

transmission system arrangement. A closed- loop transmission system

would consist of procuring an additional 69 kV breaker and lineterminal out of Xcel' s West New Ulm substation, additional

transmission improvements, and upgrades to the existing NUPU

substations for the necessary breakers and relaying. A closed loop

transmission relaying scheme would be implemented for coordinated

protection and sectionalizing of the 69 kV system.

In the past, its understood that NUPU has expressed interest in

integrating into the Midcontinent Independent System Operator

MISO) bulk transmission market. This would require NUPU to developa transmission system that would have potential to provide added

benefits to the greater system. In order to initiate a discussion with

MISO that pursues this end, a redundant closed loop system with

sufficient line ratings and capacity would likely be necessary.

Since the West New Ulm substation is property of Xcel Energy, anyconstruction improvements or additions recommended herein are

subject to review and approval by Xcel Energy. It is anticipated that

Xcel may require an internal assessment in the form of an

interconnection or transmission study, and a significant time may be



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necessary before any work is completed at the West New Ulmsubstation.

4.9. System Deficiencies: Table 4 summarizes the deficiencies found in analysis of the

voltage and capacity of NUPU' s existing electric system.

TABLE 4

SUMMARY OF DEFICIENCIES - VOLTAGE & CAPACITY

Projected Loading: System Intact, Loss of Center St.

Bus, Center St. Tie, S. Side Bus 2

Projected Loading:

Loss of Center Street Transformer

Projected Loading:

Loss of North Side Transformer

Projected Loading:

Loss of Power Plant Bus # 2

Projected Loading:

Loss of N. Side Bus

Projected Loading:

Loss of S. Side Bus 1

Projected Loading:

Loss of S. 69 kV T -line

North Side Transformer

North Side

W. Feeder ( 531W)


North Side

W. Feeder ( 531W)

Power Plant

WC -2 Fdr ( 331WC2)

W. Feeder ( 531W) Via

Center Street Sub

S. Feeder ( 5315) Via

Center Street Sub


North Side

W. Feeder ( 531W)

Power Plant

WC -2 Fdr ( 331WC2)

South Side

S. Feeder ( 433S)


Kraft Feeder ( 431K)

North Side

West Feeder ( 531W)

Center Street

South Feeder ( 233S)

MWIElectrical System Study & Capital Improvements Plan


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Capacity 23. 9 MVA

Capacity 766 A &

Voltage Drop 9. 08 V

Capacity 36.4 MVA

Capacity 766 A &





Capacity 26. 5 MVA

Capacity 766 A &

bltage Drop 9. 08 V


Capacity 486 A &

Itage Drop 4. 51 V

Capacity 23. 9 MVA

Voltage Drop 4.42 V

Capacity 766 A &



4/ 13


In addition to the voltage and capacity deficiencies listed in Table 4, the overall age,

condition and functionality of electrical equipment was assessed to determine ifreplacement would be necessary for operational dependability. While some of theequipment included in this listing is operating satisfactorily or is not currentlydeficient, it is expected that this equipment will need to be replaced in within the 20

years considered in this study. Table 5 below is a summary of these facilities.

TABLE S

SUMMARY OF DEFICIENCIES — AGE & CONDITION

Acott Equipment YwrO

69 kV Oil -Insulated Circuit Breakers 1974- 1979

2416, # 2417, # 2418 ( 39-44 Years)

Center StreetStation Post Insulators and Arresters Estimated 40- 50 Years

69- 13. 2 kV Transformer

Generator # 7 Tie - # 07451968 ( 50 Years)

Substation

Outdoor Metalclad

13. 2 kV Switchgear1970' s ( 40 Years)

Indoor Metalclad Switchgear 1950's - 1970' s

Power Plant 13. 2 kV Buses # 1 & # 2, 2. 4 kV Bus # 3 40- 60 Years)

Substation 13. 2- 2. 4 kV Tie Transformers

0750 & # 07511960' s ( 50 Years)

69 kV Oil -Insulated Circuit Breakers

4418 & # 44191980 ( 38 Years)

South Side

Substation

Indoor Metalclad 13. 2 kV

Switchgear & Relays1980 ( 38 Years)

69- 13. 2 kV Power Transformer

07431980 ( 38 Years)

69 kV

Transmission

Center Street — South Side

1 Mile of Original 69 kV Structures1960' s ( 50 Years)

The equipment listed is in generally good working order. However, it is recommended

that equipment with 50 years of use within the next planning cycle is approachingthe end of its expected useful life and should be scheduled for replacement. While it

is not uncommon for equipment to exceed 40- 50 years of successful operation, this

usually exceeds the recommendations of the manufacturer. NUPU currently has a



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regular oil testing program for its power transformers, and the oil tests are reportedly

satisfactory. We encourage continuation of this program, as well as the regular testingof circuit breakers, switchgear, protective relays and other critical electrical

infrastructure.

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Capital Improvements Plan

5. CAPITAL IMPROVEMENTS PLAN:

5. 1. General: The Capital Improvements Plan ( CIP) describes, in general, the

improvements to the system recommended over the next twenty ( 20) years

to eliminate the system deficiencies identified in this report, and to satisfy the

planning criteria listed in the previous section. The following sections detailthe proposed capital improvements for NUPU' s electric system. Project cost

estimates are based on contractor pricing that includes furnishing and

installing the materials. The estimates are based on 2nd quarter of 2018 anddo not consider the effects of inflation. Costs include allowances for

engineering and contingencies.

5. 2. Recommended Improvements: The improvements recommended for the

20 Year CIP are divided into phases and are illustrated in Figures 6 & 8 of

Appendix A of this report.

CIP Phase 1: The improvements recommended for Phase 1 are described

in this section.

Phase 1 ( A): Construct mainline distribution circuitry from existing

North Side distribution feeder to the growing northwest industrial areaof the system. The project includes:

Installation of one ( 1) underground 30 mainline circuit of

500 Cu. installed in conduit in trench

Includes two ( 2) switches and one ( 1) riser

5, 500' from Broadway & 20th N to N Highland & 280th St.

Timing: Design in 2019, construction in 2020. Required with

0- 1 MW of load growth in the northwest industrial area of the

system.

Discussion: This project is necessary to reduce voltage dropconcerns due to load growth in the northwest industrial area of

the system anticipated within the next year ( 2019). Currently,

the distribution system can maintain acceptable voltage during



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intact normal system operation. With the addition of new loads

as discussed with NUPU staff, the system would not handle the

switching contingencies without significant voltage drop on theWest Feeder circuit fed out of the North Side substation. This

additional 30 mainline circuit would provide additional line

capacity and distribute the load to maintain voltage meeting

the design criteria set forth in this study. It is recommendedthat if load growth is realized as expected, this project be

designed and constructed as soon as budgetary planningallows.

Phase 1 ( A) Estimated Cost: $ 690,000

Phase 1 ( B): Construction of new West Side substation and

associated distribution mainline circuitry. The project includes:

Substation site, steel structures, foundations, equipment,

grounding and miscellaneous equipment

Three ( 3) 69 kV breakers with switches

One ( 1) 12/ 22. 4 MVA power transformer

One ( 1) 15 kV switchgear lineup with six ( 6) breakers in a

metal control building69 kV control panels for transformer, breakers and line

protection and control

Ten ( 10) padmount switches with vacuum interrupters

Four ( 4) mainline circuits for tying to the existing

distribution system, equaling approximately 4.6 miles of 30

500 CU underground cable and associated equipment

2. 7 miles of 30 1/ 0 AL primary subloop circuitry forinterconnection of services

Timing: Design in 2019, construction in 2020. Required for

1- 2 MW of load growth in the northwest industrial area of the

system.

Electrical System Study & Capital Improvements PlanOGINew Ulm Public Utilities

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Discussion: This project is necessary to provide additionalsubstation transformer and distribution capacity to

accommodate a potential 1- 2 MW of load growth in the

northwest industrial area of the system. This portion of

phase 1 would enable the distribution system to maintain

acceptable voltage during the loss of a major electrical facility, such as a switchgear bus, power transformer, or transmission

line segment through back -feed ties on the system. With this

new circuitry and transformer capacity, the loads currently

supplied by the West Feeder circuit fed out of the North Sidesubstation would be distributed across other feeders as

necessary.

Phase 1 ( B) Estimated Cost: $ 5,990,000

Phase 1 ( C): Addition of line terminal and breaker at Xcel' s West New

Ulm substation and the construction of a 69 kV transmission line from

the Xcel terminal to the new West Side substation. The project

includes:

Installation of breakers, relaying, switches, structures andbuswork

Installation of transmission relaying equipment at the

existing North Side substation.

Coordination and planning effort with Xcel EnergyConstruction of 0. 5 miles of 69 kV transmission line

consisting of 556 ACSR on steel pole structures

Timing: Design in 2019, construction in 2020- 2021. Requiredwhen construction of the West Side substation is completed.

Time of completion is contingent upon Xcel Energy review andapproval.

Discussion: This project is necessary to provide transmission

supply to a new West Side substation from an additional

transmission source. This reconfiguring of NUPU' s source to be



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fed from the West New Ulm substation allows for independent

control, in coordination with Xcel Energy's protection scheme

and operations, of the breaker terminal for future closed looptransmission operation. As previously mentioned, this will

ultimately require review, planning and acceptance by Xcel

Energy.

z* Phase 1 ( C) Estimated Cost: $ 1, 510,000

CIP Phase 2: The improvements recommended for Phase 2 of the CIP

are described in this section.

Phase 2 ( A): Reconstruction of an 0. 9 mile segment on the existing

East Side 69 kV transmission line damaged heavily bywoodpeckers. The project includes:

Replacement of existing wood poles with new steel

poles

Installation of drilled concrete pier foundations with

steel casings for support of large deadend

structures, replacing the down guys existing on the

line todayInstallation of 556 ACSR phase and steel static

conductor

Timing: Design in 2018- 2019, construction in 2019.

Discussion: The purpose of this project is to replace severely

damaged 69 kV transmission line infrastructure in an area of

the system susceptible to woodpecker activity. The line

segment to be replaced is located in a relatively low- lying area

in and around the Minnesota River. The line was recently

assessed to determine what actions are necessary to remediate

the damage caused to -date by the woodpeckers. Attempts

have been made recently to mitigate damage by installingprotective coverings and diverters on the structures but were



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unsuccessful. The staff of NUPU has significant concerns

regarding the reliability and safety of the structures due to the

substantial holes and pits created by the woodpeckers. Steelpoles are impervious to the effects of woodpeckers and will be

a permanent solution for this area of concern. This project is

currently in the design phase, with preliminary design and soil

boring analysis completed. The preliminary analysis has

determined that the existing transmission alignment consists of

soils that are poorly suited for the structural support of concrete

pier foundations, and therefore are going to require larger and

deeper concrete foundations than initially accounted for in cost

estimates. Additional factors such as the periodic flooding and

subsequent erosion at critical deadend structures supporting

the long span crossing of the Minnesota River add additional

concerns for the ability to reconstruct the line in its existing

alignment in a timely fashion. Due to these significantly greatercosts and anticipated difficulties associated with the

construction of this segment of line, alternative transmission

routing is under consideration by NUPU staff and is included inPhase 2 ( B) of the CIP.

Phase 2 ( A) Estimated Cost: $ 1, 100,000

Phase 2 ( B): Construction of 5. 5 miles of new 69 kV transmission line

from an existing steel pole of the existing East Side69 kV line to the South Side substation. This project

would eliminate the need to rebuild the existing line

segment damaged by woodpeckers described in

Phase 2 ( A). The project includes:

Installation of steel poles for support of the 69 kV

insulators and conductors

Installation of drilled concrete pier foundations for

support of large deadend structures

Installation of 556 ACSR phase and steel or optical

ground wire for shielding



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Installation of 69 kV breaker # 4416 and associated

controls at the existing South Side substation

z* Timing: Design in 2018- 2019, construction in 2019- 2020.

Schedule contingent on preliminary feasibility analysis.

Discussion: This project would reconfigure the existing Ft.

Ridgely transmission line source from its current alignment

crossing the Minnesota River and connecting to NUPU' s 69 kV

system as a tap, to a route entering the south area of thesystem feeding into the South Side substation. This

re -alignment of the Ft. Ridley source line would create a

physical 69 kV transmission loop for the Center Street and

South Side substations. The transmission loop allows for a

back -feed if a significant transmission outage is experienced

between 19th N. Street and the South Side substation. This

project reduces or eliminates the necessity to operate

expensive fuel oil burning generators at the Center Street

substation as a backup source in the event of a 69 kV bus ortransmission outage. Also included in this part of Phase 2 is the

installation of an additional circuit breaker at the South Side

substation to accommodate the new line terminal. Relays will

be required to be upgraded for protection and control of the 69

kV bus and transmission line. A preliminary route has been

identified for this line, and will require a feasibility study to

verify the availability of property for the construction of a

transmission line along the proposed alignment, as shown inFigure 7 of the Appendix.

Phase 2 ( B) Estimated Cost: $ 2, 910,000

CIP Phase 3: Phase 3 of the 20 year CIP consists of the construction of 1. 3

miles of new 69 kV transmission line from the existing NorthSide 69 kV line to the new West Side substation. The project

includes:

nIElectrical System Study & Capital Improvements Pian


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Installation of steel poles for support of the 69 kV

insulators and conductors

Installation of drilled concrete pier foundations for

support of large deadend structures

Installation of 556 ACSR phase and steel or optical

ground wire for shieldingInstallation of 69 kV transmission switch on the

existing North Side transmission line.

Timing: Design and construction in 2020 - 2024

Discussion: This project would complete the process of

developing a 69 kV transmission loop for the electric system.

As the last piece of the long- term transmission plan, this project

enables the operation of a closed- loop transmission line relay

and breaker scheme. After relay, communications and controls

upgrades are completed at the substations, a coordinated relay

protection plan can be implemented for the automatic

sectionalizing of the 69 kV system. In this scheme, if a segmentof transmission line experiences a short or failure, relays will

sense disturbance and automatically break the circuit leavingthe load fed from the opposite source without an interruption

of service. Depending on the type of event, the relay andbreaker operations are almost instantaneous.

Phase 3 Estimated Cost: $ 1, 060,000





CIP Phase 4: The improvements recommended for Phase 4 of the CIP are

described in this section.

Phase 4 (A): Completing upgrades at the existing Center Street

substation to replace equipment that is reaching theend of its expected usable life. The project includes:

Replacement of three ( 3) oil -insulated 69 kV circuit

breakers

Replacement of the Generator # 7 69- 13. 2 kV,

12/ 22. 4 MVA rated tie transformer

Replacement of 13. 2 kV outdoor metalclad

switchgear with eleven ( 11) breakers

Replacement of porcelain station post insulators,

buswork, arresters and PT's on the existing steeldeadend box structure


Discussion: This upgrade project is necessary to maintain the

reliability of the electric system and its facilities located at theCenter Street substation. The equipment identified for

replacement will have been in use for over 40 to 50 years in

and should be budgeted for replacement in the next 5- 10 years.

Phase 4 ( A) Estimated Cost: $ 2,030,000

Phase 4 ( B): Completing upgrades at the existing Power Plant

substation to replace equipment that is reaching theend of its expected usable life. The project includes:

Replacement of 2. 4 kV and 13. 2 kV indoor metalclad

switchgear and relays

Replacement of two ( 2) 13. 2- 2.4 kV, 7. 5/ 8. 4 MVA

tie transformers

Timing: Design and Construction in 2024 - 2029

Electrical system study & Capital Improvements PlanOGMINew Ulm Public Utilities

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reliability of the electric system and its facilities located at thePower Plant substation. The equipment identified for

replacement will have been in use for over 50 to 60 years in

and should be budgeted for replacement in the next 5- 10 years.

Phase 4 ( B) Estimated Cost: $ 2, 080,000

Phase 4 (C): Completing upgrades at the existing South Side

substation to replace equipment that is reaching the

end of its expected usable life. The project includes:

Replacement of two ( 2) oil -insulated 69 kV circuit

breakers

Replacement of electromechanical relays and the

addition of 69 kV relay and controls to enhance the

loop transmission systemReplacement of one ( 1) power transformer

Replacement of 13. 2 kV switchgear and relays



reliability of the electric system and its facilities located at theSouth Side substation. The equipment identified for

replacement have not been in use as long as the Center Streetand Power Plant equipment, as the South Side substation was

constructed in the 1979- 1980 timeframe. These upgrades

should be planned in the next 15- 20 years.

Phase 4 (C) Estimated Cost: $ 1, 550,000

MMI Electrical System Study & Capital Improvements Plan


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Phase 4 ( D): Reconstruction of an approximately 1. 0 mile segment

of the existing North Side — Center Street 69 kV

transmission line of original 1960's construction. The

project includes:

Replacement of existing 50- 60 year old structures

Replacement of "wishbone" style structure framingwith modern polymer post insulators

Replacement of existing 266 ACSR phase conductorwith 556 ACSR


Discussion: This project will replace the oldest portions of the

existing 69 kV transmission line infrastructure original to theenergization of the Center Street substation. The line segment

to be replaced begins at the existing 3 -way switch where the

Ft. Ridgley source connects from the east, and continues southto the Center Street substation. A portion of the original line

along Water Street was reconstructed in the 1990' s timeframe.

The existing structures to be replaced are constructed of roundwood poles and utilize porcelain bell suspension insulators on

a " wishbone" style crossarm assembly, common for the

construction techniques of the 1960's timeframe the line is

estimated to have been completed in. Generally, the line is notconsidered a concern at this time, however replacement should

be planned due to the overall age of the structures. There is

some woodpecker activity on a few of the structures, but notto the extent of the east line. The structures should be

inspected regularly to verify structural integrity, and

replacement of structures may be necessary on an individual

basis before the total replacement of the line is necessary.

z* Phase 4 ( D) Estimated Cost: $ 610,000

Electrical system Study & Capital Improvements PlanOGINew Ulm Public Utilities



5. 3. Cost Estimate Summary: Table 6 summarizes the cost estimates for each phase

of the 20 Year Capital Improvements Plan. The estimates for major facilities

installations and upgrades to correct deficiencies based on existing and peak demand

of the electric system. These costs do not include ongoing general maintenance, overhead to underground conversion projects, replacement or installations of new

primary and secondary service installations that are necessary for the operation ofmunicipal electric system.

TABLE 6

SUMMARY OF 20 YEAR CAPITAL IMPROVEMENTS PLAN COST ESTIMATE




Load- GrpPhase Part X 01 Tlt

1 A North Side West Feeder Improvements 690, 000

B West Side Substation Construction0- 1 MW Growth

5, 990, 0002019- 2020

C Xcel Sub to West Side Sub Interconnection 1, 510,000


2 A Transmission Reconstruction — 0. 9 Miles 1, 100, 000

East Side Woodpecker Damage2019- 2020

B Transmission Construction — 5. 5 Miles 2, 910, 000

East Side to South Side Sub


3 Transmission Construction — 1. 4 Miles 1, 060, 0002020- 2024

West Side Sub to North Side Sub


4 A Center Street Sub Upgrades 2024-2029 2, 030, 000

B Power Plant Sub Upgrades 2024-2029 2, 080, 000

C South Side Sub Upgrades 2030- 2039 1, 550, 000

D Transmission Reconstruction — 1. 0 Miles2034-2039

610, 000

North Side Sub to Center Street Sub


TOTAL ESTIMATED COST — 20 YEAR CIP 19,530,000




6.

Recommendations and Conclusions

RECOMMENDATIONS AND CONCLUSIONS:

We recommend that New Ulm Public Utilities adopt this CIP as its basis for major electric

system projects over the next 20 years. We further recommend that Phases 1 and 2 be

authorized, and communications with Xcel Energy be initiated soon to begin the planning and

feasibility analysis necessary to progress forward with the projects in a timely manner.

We acknowledge the efforts of NUPU staff in the development of this study and look forward

to implementation of the improvements contained herein.

M1Electrical System Study & Capital Improvements Flan

New Ulm Pudic Utilities

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APPENDIX A

MM4 Electrical System Study & Capital Improvements Plan


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City ofNew UlmRequest for Public Utilities Commission Action

Meeting Date: July 24, 2018 Agenda Item Number: 3. a.

Agenda Section: New Business Originating Department: Electric Distribution

Resolution: N/A Prepared By: Larry Botten/ Dan Pirsig

Number of Attachments: One Presented By: Dan Pirsig

Item: Consider authorizing the City Manager to accept and sign the proposal from DGREngineering for the development of a feasibility study of options to rebuild the east sidetransmission line.


Motion by , second by authorizing the City Manager to accept and sign the proposalfor the development of a feasibility study of options to rebuild the east side transmission line from DGR Engineering atan estimated cost of $8, 000 to $ 10, 000.


Overview:

This feasibility study is in response to the escalating cost of the east side transmission line rebuild project which wasoriginally budgeted at $ 650, 000. The current preliminary cost of construction is approximately $ 1, 100, 000. The price

increase is mostly due to poor soils at the sites of the river crossing abutments.

The current project has been put on hold to give NUPUC the option of looking at more alternatives without incurring thebalance of the design costs until it is known what the best option is or if the PUC just wants this line rebuilt.

Primary Issues/Alternatives to Consider: Failure to address the damage will eventually contribute to the failure of the 69 kV crossing, NUPUC' s primary sourceof power.

Fall 2016: Discovery of significant woodpecker damage. January 2017: The Electric Distribution Department fills the damage with an osmose pole patch product and contacts

Power System Engineering ( PSE) to have a professional assessment done. March 10, 2017: The PSE pole damage assessment is presented to PUC staff.

March 2017: PUC staff requests a second opinion from DGR Engineering. April 2017: During DGR' s site visit more damage is discovered. May 18, 2017: DGR provides a report with its recommendation on what is the best corrective action. May 23, 2017: Both reports are presented to the Commission for its consideration. July 25, 2017: The Commission accepts DGR proposal for design services for the east side transmission line rebuild. May 30, 2018: Staff puts DGR on hold for the design of the east side transmission line rebuild.

Budgetary/Fiscal Issues: This project will be budgeted in 2019 and the options will be presented during the budgeting process.

Attachments:

Task Order 3 from DGR Engineering

TASK ORDER

Task Order No. 3 Effective Date:

Task Order Amendment to the

DGR ENGINEERING

Master Agreement for Professional Services

DGR Engineering ( Consultant) agrees to provide to: New Ulm Public Utilities ( Client), the

professional services described below for the Project identified below. The professional services

shall be performed in accordance with and shall be subject to the terms and conditions of the

Master Agreement for Professional Services executed by and between Consultant and Client onthe 26' h day of Jam, 20 17 .

TASK ORDER PROJECT NAME: 69 kV Transmission Line Route Feasibility Study

TASK ORDER PROJECT DESCRIPTION: Perform a high- level initial route evaluation and

assessment relating to a potential 69kV transmission line. The north terminus of the proposed

transmission line would be structure 4- 34 on the Fort Ridgley to New Ulm East transmission line. The proposed t -line would progress south easterly along Minnesota TH 21 and US Highway 14and then westerly along Highway 37 to the New Ulm South Side substation.

DGR CONTACT PERSON: Dennis Haselhoff, Project Manager

CLIENT CONTACT PERSONS: Dan Pirsig, Utility EngineerLarry Botten, Electric Distribution Supervisor

SCOPE OF WORK:

We will perform the following activities related to this project:

Make a visual observation of the line route, to identify areas of concern regardingenvironmental or historical/ cultural matters.

Contact regulatory bodies with jurisdiction in these matters, to determine if areas ofsignificant concern exist. Included will be the Minnesota Department of Transportation,

Minnesota Department of Natural Resources, US Fish and Wildlife Service, and related

entities.

Review the Minnesota Department of Transportation road plans for the Highway 21 and14 intersection, if available.

Review National Wetland Inventory List for possible wetlands along the line route. Discuss with the Minnesota Department of Transportation regarding the soil conditionsnear the Minnesota River along Highway 37 and obtain any soil boring logs that may beavailable for review.

Issue a short memo discussing the findings of the work.

FEE ARRANGEMENT: We estimate that the fee required for completing the above scope ofwork will be in the range of $8, 000 to $ 10, 000.

All Hourly tasks will be billed at the Hourly Fee Schedule then in effect. A copy of the currentHourly Fee Schedule is attached as Appendix I.

In addition to the amount relating to the personnel grade of the individuals doing the work, theonly other expenses expected to be billed directly are travel -related costs (primarily mileage); and

subsistence costs if overnight stays are required ( food and lodging). The fee amounts shown above

include an estimate of these expenses.

SPECIAL TERMS AND CONDITIONS: None

0

Title:


Client)

Authorized signature and Title)

Address:

City:_

Date:

DeWild Grant Reckert and Associates Companyd/ b/ a DGR Engineering

Consultant)

Title: Curt Dieren, Vice -President

Authorized signature and Title)

Address: 1302 South Union Street

City: Rock Rapids, IA 51246

Date:

APPENDIX I

DGR ENGINEERING

JANUARY 2018

HOURLY FEE SCHEDULE A

Personnel

Grade

Engineer

Hourly Rate

Technician

Hourly Rate

Administrative

Hourly Rate

01 86 50 45

02 92 55 47

03 97 60 50

04 103 64 54

05 112 68 58

06 122 72 62

07 132 77 66

08 142 82 70

09 152 87 76

10 163 92 83

11 174 97 90

12 185 102 99

13 198 108 116

14 204 115 145

15 210 124 190

Reimbursable Expenses:

1. Company vehicles, all at the IRS standard mileage rate in effect at the time.

2. Other travel, subsistence, lodging at actual out-of-pocket cost.

3. GPS Survey Equipment ( when used) at $31. 25 per hour.

4. ATV and UTV Equipment ( when applicable) at $ 12. 50 per hour.


Meeting Date: July 24, 2018 Agenda Item Number: 3. b.

Agenda Section: New Business Originating Department: PUC Administration

Resolution: N/A Prepared By: Derek Nelson

Number of Attachments: One Presented By: Derek Nelson

Item• Consider approving the New Ulm High School Energy Education and Research Grantapplication.


Motion by , second by to approve the energy education and research grant of $4, 000to New Ulm High School.


Overview:

New Ulm Public High School has recently applied for a grant through the New Ulm Public Utilities (NUPU). The grantoffered by the NUPU is the Energy Education and Research Grant ( EERG). The submitted application is requesting

4, 000. The money requested will help educate the students on renewable energy, specifically solar energy.

If the solar installation application and the EERG are both approved, students will begin next school year with a

curriculum. The educational experience will include the implementation of the NEED Energy & Power Curriculum. Other

possible curriculum that may still be included are Solar Energy International' s curriculum and the SunPower curriculum.

Currently this grant is not budgeted, nor has it been budgeted in the past. It is staff s belief that funds for this grant havebeen pulled from different Conservation Improvement Program ( CIP) accounts, such as Miscellaneous Education and the

School Education Program. Within the CIP accounts there is money available in our Solar Rebate Program which hasbeen discontinued. This program was budgeted last year and has now been removed from the CIP as a rebate. The Solar

Rebate Program is currently the only account within the CIP that can withstand an unexpected expenditure of this amount.


Budgetary/Fiscal Issues: This is a non -budgeted item.

Attachments:

New Ulm High School Energy Education and Research Grant Application


Energy Education and Research Grant

This form must be completed in full and mailed or dropped off to: New Ulm Public Utilities, Attn: School Grant

Application, 310 First North Street, New Ulm, MN 56073.

Name of Educational Institution N&-)

Address: d % tiii F, —{ N Gw lti ln b1ti N moo? 3

E -Mail Vt1"' z` C . G. j:kK,. s

Contact Person: A-11

Program Advisor:

Summary of proposed educational experience or curriculum including project goals, methods/ activities used, projecttimeline, and how the project will be evaluated for success. Provide a detailed breakdown of your estimated costs.

Additional pages may be attached if necessary.

H4G.r1- k ii A, 4,4, t -s 13 Z ALSO 1

r+ µ 5.1 s1. l WfP.u, 49 Prn"-

5.. Numberof anticipated participa Grade/

Age All applications will be reviewed by the New Ulm Public Utilities Director, Utility Planning and Development Engineer, andEnergy Services Representative. The review committee has the right to approve or deny any part( s) of the total grant

request. Iunderstand that if this grant request is approved verificationof expenses and program success will be required in the form of

mid - project aAffinl, roject

reports.

Signature Title: iq* t 1"rw_ 4_ / I7 1' n),. pOrganization NIXV6 ' l 56 r -B

VGrant amount requested: $

14000 Office Use

Only Meeting Date: Approved

Denied NUPU Utilities

Director: NUPU Utility Planning & Development

Engineer: NUPU Energy Services Representative: January,

1. Project Name: " Green" Powered Greenhouse

ISD# 88 Ag/ IT Greenhouse Powered by 21-, Century Green Energy, Solar Power.

2. Description of Project (including purpose, objectives, grade levels, andestimated # of students impacted)

At New Ulm High School, we are very proud of the new greenhouse that was built thissummer thanks to the generosity of several local individuals and businesses. Our goalis to transform the greenhouse into a space where we teach students about thetechnology being used to produce food today. We have already funded and includedhydroponic and aquaponic systems to our greenhouse teaching arsenal that allow us tocombine science, math, and technology to teach students about innovative andsustainable practices in food production. Our next step in accomplishing this goal is todecrease our environmental impact through the use of solar panels to power thegreenhouse with a renewable energy source.

Each year, over 225 students, grades 9- 12, take part in Agricultural/ Industrial Educationcourses at New Ulm High School. No matter which class students take, we strive to givethem opportunities to gain the skills and knowledge needed to be successful in today'sindustrial and agricultural workforces. Adding solar panels to our greenhouse would givestudents hands-on opportunities to learn about renewable, green energy for years tocome.

3. Why is the Project needed and how will it help student achievement? A truly green powered greenhouse of this magnitude would impact 9- 12 grade studentsacross multiple curricular areas, career and technical opportunities, and communityengagement opportunities. Measurement of this dynamic opportunity would highlightstudents with success/ mastery of alternative energies resources such as solar andeventually wind. In that, management, conservation and efficient production of energywould allow students a direct look at real world technologies and careers. Students willreceive real world training and application of STEM concepts and get the chance towitness current alternative energy technologies that are reshaping and erasing ourcarbon footprint. Besides these opportunity students will experience mastery inagronomy, plant science, genetics, horticulture, specie identification, disease and pestmanagement skills and management practices all while having their 21st centurygreenhouse truly going " green" by SunPower Solar Systems powering all the needs ofthe greenhouse and other power needs in the high school!

4. How can Project be evaluated for effectiveness? Implementation of SunPower Solar panels from Green Energy Products can help shapethe future workforce by allowing students to explore careers in their local communities. SunPower has educational curriculum that can be embedded in the classroom, SunPower Horizons, in which instruction can be empowering students to becomedeveloped, skilled, and interested future employees fulfilling the World' s Best Workforcemindset. SunPower Solar also provides educator workshops and a week long academyin which educators can be trained in STEM enrichment curriculum.

5. Have funds already been requested or received for the Project from othersource(s)? If so, how much and from where? We have not requested or received any other funds for adding renewable energy to thegreenhouse. Funds that fundraised from the community and businesses in the past wenttowards the structure and installation of the greenhouse, as well as the hydroponic andaquaponic systems ($ 12, 000 MEALC Grant). The Agriculture Department has fundraised, with the help of The Farm City Hub Club over $60, 000 for the current greenhouseproject. Solar and eventually wind power are directions we feel will benefit our districtand most importantly our students for the future!

6. Detailed budget

Green Energy Products, from Springfield, MN has assessed the site this past summerand can meet a project level of our needs with in solar options and wind options in thefuture. We would be seeking the full $ 15, 000 level of the grant availability and also bepursuing any remainder funds needed through alternative grants and fundraisingoptions. The solar option pending proper material selection is valued at a price point ofaround $ 22, 000. However, we can have a cheaper option developed for our needs iffurther fundraising is not being pursued. SunPower panels provide the highest efficiencyon the market. A 245 -watt panel is roughly 13.41 sq. ft. and a 327 -watt panel is just 17. 5sq. ft. Depending on the space available we should have the possibility to have a netzero energy usage and actually produce energy for other area needs in the new highschool.

15 KiloWatt Grid system concept Rough estimate: $ 22,000

Generalized Product Features

High -efficiency solar panels, SunPower Solar PanelsMaximum yields excellent with low -light and temperature, cloudy days as wellDurable construction with anti -reflective glass surface

Extremely efficient and offers a variety of placement locations and trackingoptions

Lifetime monitoring systemQualifies for 30% Federal Renewable Energy Tax Credit and RebatesUL certified, TUV, IEC, ETL approved

SunPower product warranty and 25 Year performance warranty leads theindustry. Cells have been know and can last much longer, 40 years plus.

1. You stated in your application that "Students will receive real world training and applicationof STEM concepts and get the chance to witness current alternative energy technologies thatare reshaping and erasing our carbon footprint." Please give a little bit more detail on the plan forstudent educational engagement,

1 This project will provide students the opportunity to apply skills and principals related to theproduction and transmission of clean energy. The principles associated withSTEM( Science/Technology/Engineering and Mathematics) will be used in this project and will continuefor many years. The collection of radiation, converting it into energy, calculating the energy intake todetermine the intake and usage, will meet the science, technology and mathematics components.

While exploring the infrastructure, maximizing the intake of energy through proper sun angle and therotation of the earth, will emphasize the science and engineering component of STEM. The benefits ofthis project do not stop there. We will also be teaching the value of clean energy as an ecologicalfactor and how to show the economic value through the excess production generating benefits to theschool and the community as a whole.

2. Projects need to be complete by the end of the school year. Is the remaining $ 7, 000 securedor is there a commitment to complete project by June/ July 2018 if this grant is approved?

2 We currently received a grant from the University of Minnesota in the amount of 8, 000 for ensurewe had the funds to complete the project.


Meeting Date: July 24, 2018 Agenda Item Number: 3. c.

Agenda Section: New Business Originating Department: Information Technology

Resolution: N/A Prepared By: Nate Beran

Number of Attachments: None Presented By: Nate Beran

Item: Consider the purchase of ESET Antivirus three- year renewal.


Motion by , second byrenewal from SHI in the amount of $2, 520.


to authorize the purchase of ESET Antivirus three-year

Overview:

The PUC and City changed over to ESET Endpoint Antivirus about three years ago. It has been a good solution and hasworked well for our needs. The current license expires at the end of September. The IT department recommends renewingthe license for another three-year term.

Primary Issues/ Alternatives to Consider: This is a three-year renewal. This renewal was budgeted and it is a similar cost to what it cost when first purchased in

2015.

There are other antivirus solutions available but ESET has performed well for us at a low cost. Reviews of the different

antivirus solutions on the market put ESET near the top among its peers. It has historically had one of the lowest impactson system performance compared to its peers.

Budgetary/Fiscal Issues: This is a budgeted expense. Quotes were received from SHI and CDW-G. SHI was the lowest quote.

Attachments:


Meeting Date: July 24, 2018 Agenda Item Number: 3. d.



Number of Attachments: None Presented By: Nate Beran

Item: Consider the renewal of email filtering service and support subscription.


Motion by , second by _ support subscription for $10, 350 from CDW-G.


to purchase Proofpoint Essentials three-year service and

Overview:

An email filtering checks all messages to and from our email server. Traditionally we think of it as a spam filter but mostservices do much more than that. We currently utilize Proofpoint Essentials which scans messages for spam, viruses, appropriate language, sensitive information, and malicious or suspicious links. It is common for 25% to 35% of all

messages sent to us to be spam or have malicious content. We have been utilizing Proofpoint Essentials since October2016.

Primary Issues/Alternatives to Consider: It is possible to switch to another email filtering service. When we renewed our service with Proofpoint in 2017, costswere very close for other solutions. Switching to another service also requires a considerable amount of work from ITstaff which negates the cost savings.

Not continuing with email filtering exposes the organization to an unacceptable amount of risk.

Budgetary/Fiscal Issues: This is a budgeted expense and the amount will be accounted for over three years. Proofpoint is a single -source item from

CDW-G.

Attachments:


Meeting Date: July 24, 2018 Agenda Item Number: 3. e.



Number of Attachments: One Presented By: Nate Beran

Item: Consider the purchase of a three-year license for computer management software.


Motion by , second bylicense for $8, 577 from SHI.

Board/ Commission Recommendation:

to purchase ManageEngine Desktop Central three-year

Overview:

Desktop Central is a tool that helps IT manage our computers, servers, and mobile devices. It provides a number ofcapabilities that save IT staff quite a lot of time:

Patch management — manages and automates software and Windows updates

Inventory — helps track PCs, software, and changes

Automated tasks — schedule tasks to happen at certain times

Configuration management — automated tool to make sure PCs and servers have the configurations they need tohave

Remote control — gives IT staff the ability to log in remotely to help staff immediately without having to travelfrom building to building

IT finds this software to be vital to providing the level of service City and Utility staff need from us without creating awork backlog or requiring additional staff.

This three-year subscription is also an upgrade from the Professional Edition to the Enterprise Edition. This will give us

more capabilities that we are missing today including server application patching, software prohibition, software licensetracking, EXE blocking, and more.

Primary Issues/ Alternatives to Consider: Renewal costs for the Professional Edition of Desktop Central is $ 1, 400 less over a three-year period.

Budgetary/Fiscal Issues: This is a budgeted item.

Prior to this renewal we were buying one- year licenses. There is a small discount for the multi-year license and buffers usfrom increases for the next three years.

Quotes were received from Zoho and SHI. SHI was the lowest quote.

Attachments:

Feature matrix of Desktop Central Professional vs. Enterprise

7/ 19/2018 Edition Comparison - Windows Desktop Management Tool i ManageEngine Desktop Central

ManageEngineProducts Store Partners Support

Desktop CentralDownload

Overview Features Demos Documents Get Quote Support Customers

Desktop Central - Edition Comparison Matrix

Desktop Central is available in three variants - Professional Edition, Enterprise Edition and Free Edition. The table

below provides a comparison of features available in the different editions.

i! Functional for all the computers based on the license count

d Not Available

supports all features of Desktop Central Enterprise Edition for up to 25 computers

Features Professional Enterprise Edition Free Edition

Edition

Self Service Portal

Managing Small Businesses with

Suitable ForManaging

Desktops across up to 25 computers andDesktops in LAN

WAN 25 mobile devices

Annual Subscription Price

for 50 Computers, Single US$ 795 US$ 945 N/ A

Technician

Software Deployment

Self Service Portal

Patch Management

Service Pack Deployment

Third -Party Patch

Management

https://www.manageengine. com/ products/ desktop-central/ edition- comparison- matrix. htmi? p= dci& did= 45- 2015-09- 11- 14- 05-45- 11389 1/ 4

7/ 19/ 2018 Edition Comparison - Windows Desktop Management Tool I ManageEngine Desktop Central

1 Products Store Partners SupportManageEngin

Desktop Central

https:// www. manageengine. com/ products/ desktop- central/ edition- comparison- matrix. html? p= dci& did= 45- 2015- 09- 11- 14- 05- 45- 11389 2/ 4

wnloo d


Test and Approve Patches

Asset Management

Prohibited Software

Software Metering

License Management

Remote Control V

Remote Control screen

recording

Transfer Files in Remote

Session

Voice and video call

Windows Configurations

USB Device Management

Block Exe

Power Management

Windows System Tools

User Logon Reports%

Active Directory Reports Limited

Managing Desktops Acrossyyv

WAN

https:// www. manageengine. com/ products/ desktop- central/ edition- comparison- matrix. html? p= dci& did= 45- 2015- 09- 11- 14- 05- 45- 11389 2/ 4

7/ 19/ 2018 Edition Comparison - Windows Desktop Management Tool I ManageEngine Desktop Central

ManageEngineProducts Store Partners Support

Desktop Central

Refer this document to know about Desktop Central OS comparison matrix.

Trusted by

A single pane of glass for complete desktop managementhttps:// www. manageengine. com/ products/ desktop- central/ edition- comparison- matrix. html? p= dci& did= 45- 2015- 09- 11- 14- 05- 45- 11389 314

Downlocid


Role Based Administration Q

Two Factor Authentication 0

Active Directory

Authentication

Distribution Server for

Bandwidth Optimization

Add- ons

Mobile Device Management i

OS Deployment 0

Failover Server O

Secure Gateway

Multilanguage Support

vb' I ry , ow Try Now!

Refer this document to know about Desktop Central OS comparison matrix.

Trusted by

A single pane of glass for complete desktop managementhttps:// www. manageengine. com/ products/ desktop- central/ edition- comparison- matrix. html? p= dci& did= 45- 2015- 09- 11- 14- 05- 45- 11389 314


Meeting Date: July 24, 2018 Agenda Item Number: 4.a.

Agenda Section: Claims and Estimates Originating Department: Finance

Resolution: N/A Prepared By: Janine Schapekahm

Number of Attachments: Two Presented By: Nicole Jorgensen

Item: Consider acceptance of List of Claims Paid and approval of List of Claims to Be Paid.


Motion by , second by to accept the List of Claims Paid in the amount of $2, 185, 237. 18

and approve the List of Claims to Be Paid in the amount of $366,734. 72.


Overview:

Primary Issues/Alternatives to Consider:


Attachments:

1. Report of Claims Paid; and

2. Report of Claims to Be Paid.

CITY OF NEW ULM

JULY 2018 DISBURSEMENT SCHEDULE

Report ofClaims Paid

To the Public Utilities Commission of New Ulm, Minnesota:

This is to certify that the following claims accounts, and demands have been examined, audited, and approved by me and that these claims have been paid in accordance with the provisions ofthe City Charter and are submitted for your approval.

Brian D. Gramentz, City Manager

The above claims have been approved by the Public Utilities Commission.

Dated: July 24, 2018President of the Commission

DATE AMOUNT PAID

June 27, 2018 906.64

June 30, 2018 Ach 314,293. 51

July 5, 2018 48 340.78

July 7, 2018 Ach 13, 301. 00

July 10, 2018 1, 300.00

July 11, 2018 26, 526.98

July 18, 2018 Wires 1, 204,445. 06

July 18, 2018 1, 553. 43

Sub Total 1, 610,667.40

Plus Payroll Costs as Follows.

July Pa oll 574,569.78

Grand Total 2, 185,237. 18

New Ulm, MN

Vendor Number Vendor DBA Name

Bank Code: APPUC-PUC AP Operating296500 QUICSHIP COURIERS

Payable ft Payable Type

Account Number

1020 Invoice

750-5551-331325

Check Register

OUI IU

Packet: APPKT05679 - 06/ 27/ 18 PUC manuals

OY I -) J lr By Vendor Name

Payment Date Payment Type DlscountAmount PaymentAmount Number

06/ 27/ 2018 Regular 0.00 294.30 205654

Payable Date Payable Description Discount Amount Payable Amount

Account Name Project Account Key Item Description Dist Amount

06/ 05/ 2018 deliver samples toToxicity Control Lab in 0.00 294.30

Outside lab tests deliver samples toToxicity 294.30

526500 NIERENGARTEN & HIPPERT LTD 06/ 27/ 2018 Regular

Payable # Payable Type Payable Date Payable Description

Account Number Account Name Project Account Key

1102- 06/ 22/ 18 Invoice 06/ 22/ 2018 Arbritration

73.Q- 5591- 330040 Legalfees

1105- 06122/ 18 Invoice 06/ 22/ 2018 NAC ( Northern Air Corp) 710-5517-530100 Boiler plant improvement

1106-06/ 22/ 18 Invoice 06/ 22/ 2018 PUC v. Fairfax

730-5591- 330040 Legalfees

0.00 600.34 205655

Discount Amount Payable Amount

Item Description Dist Amount

0.00 230.90

Arbritration 230.90

0.00 184.72

NAC ( Northern Air Corp) 184.72

0.00 184.72

PUC v. Fairfax 184.72

540100 O' BRIEN, DAVE 06/ 27/ 2018 Regular 0.00 12.00 205656

Payable # Payable Type Payable Date Payable Description Discount Amount Payable Amount

Account Number Account Name Project Account Key Item Description Dist Amount

INV0009693 Invoice 06/ 20/ 2018 Rmb per diem 6/ 20/ 18 0.00 12. 00

730-5591-333050 Travel conferences & sch Rmb per diem 6/ 20/ 18 12.00

6/ 27/ 2018 11: 23: 05 AM Page 1 of 2

Bank Code APPUC Summary

Payable Payment

Payment Type Count Count Discount Payment

Regular Checks 5 3 0.00 906.64

Manual Checks 0 0 0.00 0.00

Voided Checks 0 0 0.00 0.00

Bank Drafts 0 0 0.00 0.00

EFT' s 0 0 0.00 0.00

S 3 0.00 906.64

6/ 27/ 2018 11: 23: 05 AM Page 1 of 2

v*. New Ulm, MN

4


Bank Code: APPUC- PUC AP Operating

453100 MIDWEST ISO

Payable # Payable Type

Account Number

1552789 Invoice

710-202010

Check RegisterPacket: APPKT05692 - 06/ 30/ 18 MISO

px v w3011V By Vendor Name

Payment Date Payment Type Discount Amount PaymentAmount Number

06/ 30/ 2018 Bank Draft 0.00 32, 986.51 DFT0004979

Payable Date Payable Description Discount Amount Payable Amount

Account Name Project Account Key Item Description Dist Amount

05/ 29/ 2018 May MISO energy 0.00 32, 986. 51

Accounts payable purcha May MISO energy 32, 986.51

453100 MIDWEST ISO 06/ 30/ 2018 Bank Draft 0.00 114.04 DFT0004980



1552790 Invoice 05/ 29/ 2018 Admin. fee 0.00 114.04

710-5516- 2.26350 Purchased power energy Admin. fee 114. 04

453100 MIDWEST ISO 06/ 30/ 2018 Bank Draft 0. 00 47,041. 86 DFT0004981



1554266 Invoice 06/ 05/ 2018 May MISO energy 0.00 47,041.86

710- 20201.0 Accounts payable purcha May MISO energy 47,041. 86

453100 MIDWEST ISO 06/ 30/ 2018 Bank Draft 0. 00 124.97 DFT0004982



X55426_7 Invoice 06/ 05/ 2018 Admin. fee 0. 00 124.97

710- 5516-226350 Purchased power energy Admin. fee 124. 97

453100 MIDWEST ISO 06/ 30/ 2018 Bank Draft 0.00 116, 314.63 DFT0004983



8496/ 79601 Invoice 06/ 07/ 2018 MISO May transmission 0.00 116, 314.63

710-202010 Accounts payable purcha MISO May transmission 116, 314.63

453100 MIDWEST ISO 06/ 30/ 2018 Bank Draft 0.00 4,080.93 DFT0004984



8496179602 Invoice 06/ 07/ 2018 MISO May transmission 0.00 4,080.93

710-202010 Accounts payable purcha MISO May transmission 4,080.93

453100 MIDWEST ISO 06/ 30/ 2018 Bank Draft 0. 00 2,471.43 DFT0004985


Account Number Account Name Project Account Key Rem Description Dist Amount

8496119610 Invoice 06/ 07/ 2018 MISO May transmission 0. 00 2,471.43

71.0- 20207.0 Accounts payable purcha MISO May transmission 2, 471.43

453100 MIDWEST ISO 06/ 30/ 2018 Bank Draft 0.00 70,661. 27 DFF0004986

Payable It Payable Type Payable Date Payable Description Discount Amount Payable Amount


1555226 Invoice 06/ 12/ 2018 May MISO energy 0.00 70, 661.27

710- 202010 Accounts payable purcha May MISO energy 70,661. 27

453100 MIDWEST ISO 06/ 30/ 2018 Bank Draft 0. 00 217. 76 DFT0004987

Payable It Payable Type Payable Date Payable Description Discount Amount Payable Amount


1555227 Invoice 06/ 12/ 2018 Admin. fee 0.00 217.76

710- 5516- 226350 Purchased power energy Admin. fee 217.76

7/ 5/ 12018 4: 08: 2,, FM Page 1 of 3

Check Register Packet: APPKTO5692- 06/ 30/ 18 MISO

Vendor Number Vendor DBA Name Payment Date Payment Type Discount Amount Payment Amount Number

453100 MIDWEST ISO 06/ 30/ 2018 Bank Draft 0. 00 - 0. 05 DFT0004988



06/ 07/ 2018 Credit Memo 06/ 07/ 2018 MISO transmission 0.00 0. 05

7.10; 5516__226351 Purchased power transmi MISO transmission 0. 05

453100 MIDWEST ISO 06/ 30/ 2018 Bank Draft 0.00 40, 117.38 DFT0005031



1556181 Invoice 06/ 19/ 2018 June MISO energy 0.00 40,117. 38

710-202010 Accounts payable purcha June MISO energy 40, 117. 38

453100 MIDWEST ISO 06/ 30/ 2018 Bank Draft 0.00 162. 78 DFT0005032



1.556182 Invoice 06/ 19/ 2018 Admin. fee 0.00 162. 78

710-5516- 226350 Purchased power energy Admin. fee 162. 78

Bank Code APPUC SummaryPayable Payment


Regular Checks 0 0 0.00 0. 00

Manual Checks 0 0 0.00 0. 00

Voided Checks 0 0 0.00 0. 00

Bank Drafts 12 12 0. 00 314,293. 51

EFT' s 0 0 0.00 0. 00

12 12 0. 00 314,293.51

i8 4: 08: 28 PM Paye 2 of 3

New Ulm, MN

Vendor Number Vendor DBA Name Payment Date


Check RegisterPacket: APPKT055709 - 07/ 05/ 18 PUC manuals

NL I I ( I X By Vendor NameU

Payment Type Discount Amount Payment Amount Number

Void** 07/ 05/ 2018 Regular 0.00 0. 00 205865

012500 ABDO EICK & MEVERS LLP 07/ 05/ 2018 Regular 0.00 3, 564.00 205861



401903 -PUC Invoice 06/ 29/ 2018 Audit services 0. 00 3, 564.00

760- 5591-330025 Auditing fees Audit services 3, 564.00

171450 CHUCK SPAETH FORD INC 07/ 05/ 2018 Regular 0.00 40, 125. 20 205862



NT197720 Invoice 06/ 11/ 2018 Best quote for 2018 F -Series SD Ford Truc 0.00 40,125. 20

710- 5577-540000 Vehicles Best quote for 2018 F -Seri 40,125. 20

203900 CUNNINGHAM, RACHEL 07/ 05/ 2018 Regular 0.00 141. 53 205863



INV0009789 Invoice 06/ 19/ 2018 Rmb per diem & fuel expense 6/ 19- 6/ 21 0. 00 141. 53

750- 5551 221050 Vehicle & Equip Unl Gas Rmb fuel expense 6/ 19- 6/ 47.53

750-5591- 333050 Travel conferences & sch Rmb per diem 6/ 19- 6/ 21 94.00

523750 NEW ULM TELECOM INC 07/ 05/ 2018 Regular 0.00 4,485.03 205864



82348275 Invoice 07/ 01/ 2018 July phone/ June long dist 0. 00 4, 485.03

71.0- 5533- 222320 Station equipment July phone 79. 95

710- 5591-332100 Communications July phone/ June long dist 498.06

720-5591- 332100 Communications July phone/ lune long dist 15. 91

730-5573 222005 Maintenance buildings July phone 43.61

730-5591-332100 Communications July phone/ June long dist 227.03

740-5513- 222235 Water filter treatment pl July phone 90.89

740-5591- 332100 Communications July phone/ June long dist 150. 37

750- 5591- 33210 Communications July phone/ June long dist 301.87

760-5591- 221055 Fuel depot July phone 10.94

760-5591- 332100 Communications July phone/ June long dist 428.29

760-5591- 332100 Communications July phone/ June long dist 14.51


765-5591- 332100 Communications July phone 2, 522. 20


7/ 5/ 2018 5: 15: 18 PM Paye 1 of 3

Check Register Packet: APPKT05709-07/ 05/ 18 PUC manuals


748045 VERIZON WIRELESS 07/ 05/ 2018 Regular 0.00 25. 02 205866

Payable tt Payable Type Payable Date Payable Description Discount Amount Payable Amount


9809709077PUC Invoice 06/ 23/ 2018 SCADA System Device 0.00 25.02

750- 5591. 332100 Communications SCADA System Device 25. 02


Payable Payment


Regular Checks 5 5 0.00 48,340.78




EFf' s 0 0 0.00 0. 00

5 6 0.00 48,340.78

7,`5/ X;18 5: 15: 18 PM Pa9`: 2 ,of 3

A,

IF. Y

zr



Bank Code: APPUC-PUC AP Operating

Payable

475505 MN STATE- COMM OF REV


Count

Account Number Acco

JUNE2018- PUC Invoice

0

710- 141001 Inve

710-202051 Sale

710-5513- 222001 Tool

710-5513- 222005 Mai

710-5513- 222350 Boile

710-5513- 222351 Elect

710-5513- 222357 Gas

710-5513- 226010 Sup710-5571- 222025 Mai

710-5571- 348210 Cust

710-5573- 222001 Tool

710-5573- 222005 Mai

710-5573- 222305 Lines

710-5577- 530500 Stre

710-5591- 220010 Offic

730-5571- 226010 Sup730-5571-331450 Leak

730-5573- 222001 Tools

730-5573- 222005 Mai

730-5573- 222140 Mai

760-202050 Sale

760-202050 Sale

760-202051 Sale

760-5591- 220010 Offic

760-5591- 221055 Fuel

760-5591- 222025 Mai

7760- 5593-222005 Mai

7.60-5601-350010 Misc

760-5616-381012 Air c

760-5621- 221010 Misc

760-5623- 222001 Tools

760-5623-222005 Mai

760-5641-350010 Misc

765-5591-220010 Offic

765-5591- 224100 Com

Check RegisterPacket: APPKTO5715 - 07/ 07/ 18 PUC sales tax

Pu " I I I ( V By Vendor Name

Payment Date Payment Type Discount Amount Payment Amount Number

07/ 07/ 2018 Bank Dra

Payable Date Payable Description

unt Name Project Account Key07/ 07/ 2018 June2018 use tax & sales tax

ntory materials & sup

Sales tax payable miscella

s & equipment

Main buildings

r plant

ric plant

turbine

Supp

Main vehicles

omer service expens

s & equipment

Main buildings

underground

et light installations

e supplies

Suppdetection

equipment

Main buildings

Main & accessories

Sales tax payable utility bi

Sales tax payable utility biSales tax payable miscella

e supplies

depot

ntenance vehicles

Main buildings

ellaneous

onditioning rebate

small parts

equipment

Main buildings

ellaneous

e supplies

puter supplies & equ

ft 0. 00 13, 301. 00 DFT0005033



0. 00 13, 301. 00

June2018 use tax 445. 70

June2018 Sundry sales 86. 69



















June2018 sales tax 97, 124. 87

June estimated payment - 85, 227. 00

June2018 sales tax 216. 08













Discount

0. 00

0. 00

0. 00

0. 00

0. 00

0. 00

Payment

0. 00

0. 00

0. 00

13, 301. 00

0. 00

13, 301. 00

7/ 7/ 2018 9: 45: 54 AM Page 1 of 2


Payable Payment

Payment Type Count Count

Regular Checks 0 0

Manual Checks 0 0

Voided Checks 0 0

Bank Drafts 1 1

EFT' s 0 0

1 1

ft 0. 00 13, 301. 00 DFT0005033



0. 00 13, 301. 00


June2018 Sundry sales 86. 69



















June2018 sales tax 97, 124. 87

June estimated payment - 85, 227. 00

June2018 sales tax 216. 08













Discount

0. 00

0. 00

0. 00

0. 00

0. 00

0. 00

Payment

0. 00

0. 00

0. 00

13, 301. 00

0. 00

13, 301. 00

7/ 7/ 2018 9: 45: 54 AM Page 1 of 2

Discount

0.00

0.00

0.00

0.00

0.00

0.00

Payment

0.00

0.00

0.00

13, 301.00

0.00

13, 301.00

7/ 7/ 2018 9: 45: 54 AM Page 1 of 2

7/ 10% 2- G! 8 L0: 42: 44 AM Pa_ a 1 0f

Check RegisterNew Ulm, MN Packet: APPKT05720 - 07/ 10/ 18 PUC manual

Poe.,, J/ O// By Vendor Namet


Bank Code: APPUC- PUC AP Operating564500 POSTMASTER 07/ 10/ 2018 Regular 0. 00 1, 300.00 205886



INV0009790 Invoice 07/ 10/ 2018 Postage stamps 0. 00 1, 300.00

760-5591- 332100 Communications Postage stamps 1, 300.00


Payable Payment


Regular Checks 1 1 0.00 1, 300.00




EFf' s 0 0 0.00 0.00

1 1 0.00 1, 300.00

7/ 10% 2- G! 8 L0: 42: 44 AM Pa_ a 1 0f

t.

New Ulm, MN

Vendor Number Vendor DBA Name Payment Date Payment Type

Bank Code: APPUC-PUC AP Operating201500 Professional Credit Analysts of Minn 07/ 11/ 2018 Regular


Account Number Account Name Project Account Key

010835-JUNE201 Invoice 06/ 29/ 2018 June 2018 PCA collections

710-5591-350010 Miscellaneous

720-5591- 350010 Miscellaneous


740-.5591-350010 Miscellaneous


232915 DIETZ, JOE


Account Number

03086712904 Invoice

710-5591-347110

273900 FISCHER, MICHAEL


Account Number

IN V000_9797 Invoice

710-5591-347110

950909 MATHIOWETZ, KEVIN


Account Number

INV00097g9 Invoice

740-5591-333050

07/ 11/ 2018 Regular


Account Name Project Account Key07/ 11/ 2018 Rmb license fees

Permits fees & leases

07/ 11/ 2018 Regular


Account Name Project Account Key

07/ 11/ 2018 Rmb license fees & textbook

Permits fees & leases

07/ 11/ 2018 Regular


Account Name Project Account Key06/ 28/ 2018 Rmb per diem 06/ 28/ 18

Travel conferences & sch


P u L I I I I r By Vendor Name

Discount Amount Payment Amount Number

0. 00 80. 00 205889



0. 00 80. 00

Rmb license fees 80. 00

0. 00 114. 52 205890



0. 00 114. 52

Rmb license fees & textbo 114. 52

0. 00 46. 00 205896



0. 00 46. 00

Rmb per diem 06/ 28/ 18 46. 00

475950 Rooms and Rest 07/ 11/ 2018 Regular 0. 00 337. 00 205892



1168770 Invoice 06/ 06/ 2018 Reception area chairs & end table 0. 00 337. 00

750- 5591- 220010 Office supplies Reception area chairs & en 337. 00

475560 MN STATE - UI FUND 07/ 11/ 2018 Regular 0. 00 9, 282. 00 205891



12093504 - PUC Invoice 07/ 11/ 2018 Unemployment benefits paid 0. 00 9, 282. 00

760- 5601- 7. 14100 Unemployment Unemployment benefits p 9, 282. 00

000755 PRICE, NICK


Account Number

IN, V0009796 Invoice

740- 5591- 333050

622980 SCHNEIDER, JAIME


Account Number

INV0009. 98 Invoice

740- 5591- 33. 3050

07/ 11/ 2018 Regular



06/ 28/ 2018 Rmb per diem 6/ 28/ 18


07/ 11/ 2018 Regular




0. 00 46. 00 205887



0. 00 46. 00

Rmb per diem 6/ 28/ 18 46. 00

0. 00 46. 00 205893



0. 00 46. 00

Rmb per diem 6/ 28/ 18 46. 00

7/ 11. 12018 3: 58: 51 PM Paye 1 of 3

0. 00 419. 21 205888



0. 00 419.21

June 2018 PCA collections 222. 18




June 2018 PCA collections 117.38

0. 00 80. 00 205889



0. 00 80. 00

Rmb license fees 80. 00

0. 00 114. 52 205890



0. 00 114. 52

Rmb license fees & textbo 114. 52

0. 00 46. 00 205896



0. 00 46. 00

Rmb per diem 06/ 28/ 18 46. 00

475950 Rooms and Rest 07/ 11/ 2018 Regular 0. 00 337. 00 205892



1168770 Invoice 06/ 06/ 2018 Reception area chairs & end table 0. 00 337. 00

750- 5591- 220010 Office supplies Reception area chairs & en 337. 00

475560 MN STATE - UI FUND 07/ 11/ 2018 Regular 0. 00 9, 282. 00 205891



12093504 - PUC Invoice 07/ 11/ 2018 Unemployment benefits paid 0. 00 9, 282. 00

760- 5601- 7. 14100 Unemployment Unemployment benefits p 9, 282. 00

000755 PRICE, NICK


Account Number

IN, V0009796 Invoice

740- 5591- 333050

622980 SCHNEIDER, JAIME


Account Number

INV0009. 98 Invoice

740- 5591- 33. 3050

07/ 11/ 2018 Regular



06/ 28/ 2018 Rmb per diem 6/ 28/ 18


07/ 11/ 2018 Regular




0. 00 46. 00 205887



0. 00 46. 00

Rmb per diem 6/ 28/ 18 46. 00

0. 00 46. 00 205893



0. 00 46. 00

Rmb per diem 6/ 28/ 18 46. 00

7/ 11. 12018 3: 58: 51 PM Paye 1 of 3

Check Register Packet: APPKTO5735- 07/ 11/ 18 PUC manuals


736400 UNITED FARMERS COOPERATIVE 07/ 11/ 2018 Regular 0.00 15, 913. 21 205894



108452 Invoice 06/ 22/ 2018 Unleaded gasoline 0.00 2, 289.41

710- 141017 Fuel - unleaded Unleaded gasoline 2, 289.41

108453 Invoice 06/ 22/ 2018 Diesel gasoline 0.00 2, 569.20

710- 141016 Fuel - diesel Diesel gasoline 2, 569. 20

33122 Invoice 06/ 06/ 2018 Diesel gasoline 0.00 1, 848. 98

710- 141016 Fuel - diesel Diesel gasoline 1, 848.98

33123 Invoice 06/ 06/ 2018 Unleaded gasoline 0.00 3, 477. 69

710- 141017 Fuel - unleaded Unleaded gasoline 3, 477.69

33124 Invoice 06/ 15/ 2018 Unleaded gasoline 0.00 3,076. 33

710-141017 Fuel - unleaded Unleaded gasoline 3, 076.33

33125 Invoice 06/ 15/ 2018 Diesel gasoline 0.00 2,651. 60

710-141016 Fuel - diesel Diesel gasoline 2, 651.60

748045 VERIZON WIRELESS 07/ 11/ 2018 Regular 0. 00 243. 04 205895

Payable p Payable Type Payable Date Payable Description Discount Amount Payable Amount


9809707782 Invoice 07/ 03/ 2018 05/ 24/ 18- 06/ 23/ 18 services 0. 00 243. 04

740-5591- 332100 Communications 05/ 24/ 18- 06/ 23/ 18 servic 243. 04


Payable Payment


Regular Checks 15 10 0.00 26, 526. 98

Manual Checks 0 0 0.00 0. 00


Bank Drafts 0 0 0.00 0. 00

EFT' s 0 0 0.00 0.00

15 10 0.00 26, 526.98

7/ 1112018 3: 58: 51 PM Fay<; 2 , t 3

Check Register

New Ulm, MN Packet: APPKT05757 - 07/ 18/ 18 PUC wires

1 YO By Vendor Name



110450 BP CANADA ENERGY MARKETING CC 07/ 18/ 2018 Bank Draft 0.00 1, 281. 87 DFT0005084



5553147 Invoice 07/ 06/ 2018 Tyler June gas 0.00 1, 281.87

730-4000-37190 Outside utility sales Tyler June gas 1, 281.87

110450 BP CANADA ENERGY MARKETING CC 07/ 18/ 2018 Bank Draft 0.00 154,776. 15 DFT0005085



5553143 Invoice 07/ 05/ 2018 June fuel 0.00 154,776.15

710- 202010 Accounts payable purcha June BP Powerplt 46,386.00

730- 202010 Accounts payable purcha June PB town 106,092.60

730-4000-37190 Outside utility sales June Fairfax BP 2, 297.55

110450 BP CANADA ENERGY MARKETING CC 07/ 18/ 2018 Bank Draft 0. 00 3, 516.77 DF170005086


Account Number Account Name Project Account Key Item Description DistAmount

5553146 Invoice 07/ 06/ 2018 Morgan June gas 0.00 3, 516.77

730-4000-37190 Outside utility sales Morgan June gas 3, 516. 77

316350 HEARTLAND CONSUMERS POWER D 07/ 18/ 2018 Bank Draft 0. 00 978,336.93 DFT0005088



JUNE2018 Invoice 07/ 11/ 2018 lune HCPD energy & transmission 0. 00 978,336.93

730-202010 Accounts payable purcha lune HCPD energy 874,529.28

730-202010 Accounts payable purcha June HCPD transmission 103,807. 65

330800 HUTCHINSON UTILITY 07/ 18/ 2018 Bank Draft 0. 00 660.00 DFT0005081



07012018NUI Invoice 07/ 02/ 2018 Aug. NU interconnect 0. 00 660.00

730-5573- 222142 High pressure mains Aug. NU interconnect 660.00

330800 HUTCHINSON UTILITY 07/ 18/ 2018 Bank Draft 0.00 660.00 DFI-0005082



07012018FI Invoice 07/ 02/ 2018 FF Aug. interconnect 0.00 660.00

730-4000-37190 Outside utility sales FF Aug. interconnect 660.00

330800 HUTCHINSON UTILITY 07/ 18/ 2018 Bank Draft 0.00 61, 620.90 DFT0005083



070120187 Invoice 07/ 02/ 2018 Hutchinson Aug. capacity 0.00 61, 620.90

730.202010 Accounts payable purcha Hutchinson Aug. capacity 61, 620.90

7/ 1. 8/ 20113 11: 39: 12 AM Page 1 of 3

Check Register Packet: APPKTO5757-07/ 18/ 18 PUC wires


765150 WESTERN AREA POWER ADMIN. 07/ 18/ 2018 Bank Draft 0.00 3, 592.44 DF10005087


Account Number Account Name Project Account Key item Description Dist Amount

BFPB00647061.8 Invoice 07/ 11/ 2018 June WAPA energy 0. 00 3, 592.44

710-202010 Accounts payable purcha June WAPA energy 3, 592. 44


Payable Payment


Regular Checks 0 0 0.00 0. 00



Bank Drafts 8 8 0.00 1, 204,445.06

EFi's 0 0 0.00 0. 00

8 0.00 1, 204.445.06

7/ 18/ 2018 1:: 39: 12 AM Page 2 , f 3

New Ulm, MNs s


Bank Code: APPUC- PUC AP Operating091552 BENDIX, JOHN


Account Number

INVO009885 Invoice

760-5641-333050


r) IolU By Vendor Name

Payment Date Payment Type Discount Amount Payment Amount Number

07/ 18/ 2018 Regular



07/ 13/ 2018 Rmb expenses- ESRI conf.


155020 CARDMEMBER SERVICE 07/ 18/ 2018 Regular


Account Number Account Name Project Account Key06/ 06/ 18- 07/ 05/ Invoice 07/ 05/ 2018 July 2018 statement

710-141001 Inventory materials & sup710-141001 Inventory materials & sup710-5591-333050 Travel conferences & sch

730-5573- 222001 Tools & equipment

750-5591-333050 Travel conferences & sch

760-5583-222001 Tools & equipment

760-5591-347040 Subscriptions & members

765- 5591-330011 PC Network Support

R01248 DOMEIER, NICK


Account Number

INV0009887 Invoice

710-5591-333050

687500 SUTHERLAND, KEN


Account Number

INV0009886 Invoice

710-5591-333050

07/ 18/ 2018 Regular




07/ 18/ 2018 Regular




0.00 622.42 205910



0.00 622.42

Rmb expenses- ESRI conf. 622.42

0. 00 12. 00 205913


Item Description DistAmount

0. 00 12. 00

Rmb per diem 7/ 12/ 18 12. 00

0. 00 12. 00 205912



0. 00 12. 00

Rmb per diem 7/ 12/ 18 12. 00

0.00 907.01 205911



0. 00 907.01

Bug Soother refund 3. 84

Bug Soother 135. 59

Hotel refund 108.99

AD/ DC Power Converter 19. 99

Hotel - R Cunningham 394.00

Pocket Protectors - Meter 7. 78

PE License - D Pirsig 122. 50

SSL Renewal 339. 98

0. 00 12. 00 205913



0. 00 12. 00

Rmb per diem 7/ 12/ 18 12. 00

0. 00 12. 00 205912



0. 00 12. 00

Rmb per diem 7/ 12/ 18 12. 00

7/ 18/ 2018 3: 42: 59 PM Page 1 of 2


Payable Payment


Regular Checks 4 4 0. 00 1, 553.43

Manual Checks 0 0 0. 00 0.00

Voided Checks 0 0 0. 00 0.00

Bank Drafts 0 0 0. 00 0.00

EFT' s 0 0 0. 00 0.00

4 4 0.00 1, 553.43

7/ 18/ 2018 3: 42: 59 PM Page 1 of 2

CITY OF NEW ULM

JULY 2018 DISBURSEMENT SCHEDULE

Report ofClaims to be Paid

To the Public Utilities Commission ofNew Ulm, Minnesota;

This is to certify that the following claims accounts, and demands have been examined, audited, and approved by me in accordance with the provisions of the City Charter and are submitted foryour approval.

Brian D. Gramentz, City Manager

The above claims have been approved by the Public Utilities Commission.

Dated: July 24, 2018President of the Commission

FUND DESCRIPTION AMOUNT TO BE PAID

710 Electric Department 191, 669.42

720 Steam Department 19, 576.99

730 Natural Gas Department 14, 767.40

740 Water Department 75, 093. 17

750 Wastewater Treatment Plant 14, 728.73

760 Administrative 49, 162. 87

765 Information Technology 1, 736. 14

Grand Total 366,734.72

New Ulm, MN

Expense Approval Report

By Vendor Name

Post Dates - 07/ 19/ 2018

Vendor Name Payable Number Post Date Description (Item) Account Number Amount

Vendor: R01250 - ABG INVESTMENTS LLC

ABG INVESTMENTS LLC RBT-07/ 2018 07/ 19/ 2018 RBT ABG INVESTMENTS -HIGH 760-5616-381022 409.40

Vendor R02250 ABG INVESTMENTS LLC Total: 409.40

Vendor: 017495 - ADAMS LAWN CARE

ADAMS LAWN CARE 2- 18 07/ 19/ 2018 Lawn Maintenance 720- 5573- 222005 34. 00

ADAMS LAWN CARE 2- 18 07/ 19/ 2018 Lawn Maintenance 740-5513- 222233 100. 00

ADAMS LAWN CARE 2- 18 07/ 19/ 2018 Lawn Maintenance 740-5513- 222233 100.00

ADAMS LAWN CARE 2- 18 07/ 19/ 2018 Lawn Maintenance 740-5573- 222005 306. 00


ADAMS LAWN CARE 2- 18 07/ 19/ 2018 Lawn Maintenance 740-5573-222222 200.00




Vendor 017495 ADAMS LAWN CARE Total: 1, 510.00

Vendor: 022000 - AHRENS HEATING & AIR CONDITIONING, INC

AHRENS HEATING & AIR CON 5742 07/ 19/ 2018 RBT Ahrens - (46) AC C& C 760-5616-381012 1, 840.00

Vendor 022000- AHRENS HEATING & AIR CONDITIONING, INC Total: 1, 840.00

Vendor: R01251- AIKEN, JOHN

AIKEN, JOHN RBT-07/ 2018 07/ 19/ 2018 RBTAIKEN - AC 760-5616- 381012 200.00

Vendor R01251- AIKEN, JOHN Total: 200.00

Vendor: 024350 - ALPHA WIRELESS COMMUNICATIONS COMPANY

ALPHA WIRELESS COMMUNIC 696303 07/ 19/ 2018 Monthly radio maintenance 710-5591-332100 400.10

ALPHA WIRELESS COMMUNIC 696303 07/ 19/ 2018 Monthly radio maintenance 720-5591- 332100 10. 20





ALPHA WIRELESS COMMUNIC 696303 07/ 19/ 2018 Monthly radio maintenance 760- 5591- 332100 54. 91

ALPHA WIRELESS COMMUNIC 696415 07/ 19/ 2018 radio battery 710-5573- 222001 111. 80



Vendor 024350 - ALPHA WIRELESS COMMUNICATIONS COMPANY Total: 1,009.90

Vendor: 059090 - AUTO VALUE NEW ULM

AUTO VALUE NEW ULM 10260296 07/ 19/ 2018 drill bits 710-5573- 222001 35. 65

AUTO VALUE NEW ULM 10261822 07/ 19/ 2018 battery- truck# 11 710-5571- 222025 228.00

AUTO VALUE NEW ULM 10261947 07/ 19/ 2018 14oz PM Red Hi Temp 720-5573- 222140 28. 90

AUTO VALUE NEW ULM 10262231 07/ 19/ 2018 Toggle switch for Dodge picku 730-5573- 222001 8. 99

AUTO VALUE NEW ULM 10262299 07/ 19/ 2018 hose, flare 710-5571- 222025 14. 49

AUTO VALUE NEW ULM 10262417 07/ 19/ 2018 Strobe light for Ranger 730-5571- 222025 73. 99

AUTO VALUE NEW ULM 10263200 07/ 19/ 2018 hose clamps 710-5513- 222357 0. 89

AUTO VALUE NEW ULM 10263844 07/ 19/ 2018 70PSI Valve 740-5513- 222235 9. 99

Vendor 059090 - AUTO VALUE NEW ULM Total: 400.90

Vendor: 059165 - AUTOMATIC SYSTEMS CO

AUTOMATIC SYSTEMS CO 32645S 07/ 19/ 2018 Wells 4 & 6 740-5513- 222230 2, 841. 45

Vendor 059165 - AUTOMATIC SYSTEMS CO Total: 2, 841.45

Vendor: 087925 - BCN TELECOM, INC

BCN TELECOM, INC 22529799 07/ 19/ 2018 June 2018 Charges - 877# 730-5591- 332100 17. 88

Vendor 087925 - BCN TELECOM, INC Total: 17. 88

Vendor: R01252 - BERANEK, JAYSON

BERANEK, JAYSON RBT- 07/ 2018 07/ 19/ 2018 RBT BERANEK - AC 760- 5616- 381012 275. 00

19/ 20,31 8 12: 43: 47 PM Page 1 of 17


Amount

RBT BERANEK - FURNACE & V 760- 5616- 381010

Vendor Name Payable Number Post Date

BERANEK, JAYSON RBT-07/ 2018- 1 07/ 19/ 2018

Vendor: R01183 - BODDY, JERRY

RBT Boddy - Furnace fan 760- 5616- 381010

BODDY, JERRY RBT7/ 2018. 1 07/ 19/ 2018

BODDY, JERRY RBT 7/ 2018.2 07/ 19/ 2018

BODDY, JERRY RBT7/ 2018.2 07/ 19/ 2018

Vendor: 109500 - BORDER STATES ELECTRIC SUPPLY

917. 82

BORDER STATES ELECTRIC SU 915480151 07/ 19/ 2018






Vendor: 112660- BREGEL, HEATHER

54. 73

BREGEL, HEATHER RBT7/ 2018 07/ 19/ 2018

Vendor: 915828 - BROWNFIELD, SHEILA

ball valve, gasket 750- 5553- 222010

BROWNFIELD, SHEILA RBT 7/ 2018 07/ 19/ 2018

Vendor: 916852 - CARDA, LELONNIE M.

307. 05

CARDA, LELONNIE M. RBT 7/ 2018 07/ 19/ 2018

Vendor: 158100 - CARROLL DISTRIBUTING & CONSTR SUPPLY INC

CARROLL DISTRIBUTING & CO NU023080 07/ 19/ 2018

CARROLL DISTRIBUTING & CO NU023088 07/ 19/ 2018

Vendor: 158400 - CARTER PUMP LLC

24. 85

CARTER PUMP LLC 170155 07/ 19/ 2018

Vendor: 160000 - CB ELECTRIC INC

Vendor 183670 - COMCAST Total:

CB ELECTRIC INC 31019 07/ 19/ 2018

CB ELECTRIC INC 31021 07/ 19/ 2018

Vendor: 162300 - CENTRAL REGION COOPERATIVE

Lid covers, valve box risers 710- 141001

CENTRAL REGION COOPERATI 31525 07/ 19/ 2018

Vendor: 181350 - COBORN' S INC

1, 429. 76

COBORN' S INC INV0009791 07/ 19/ 2018

COBORN' SINC INV0009791 07/ 19/ 2018

Vendor: 183670 - COMCAST

COMCAST INV0009805 07/ 19/ 2018

Vendor: 187600 - COMPUTER TECHNOLOGY SOLUTIONS INC.

COMPUTER TECHNOLOGY SO 61626 -PUC 07/ 19/ 2018

Vendor: 316125 - CORE & MAIN LP

CORE & MAIN LP J078139 07/ 19/ 2018

CORE & MAIN LP J113077 07/ 19/ 2018

Vendor: 197950 - CORPORATE GRAPHICS COMMERCIAL

CORPORATE GRAPHICS COM 1349398 07/ 19/ 2018

Post Dates: - 07/ 19/ 2018

Description ( item) Account Number Amount

RBT BERANEK - FURNACE & V 760- 5616- 381010 250.00

Vendor R01252 - BERANEK, JAYSON Total: 525.00

RBT Boddy - Central AC 760-5616-381012 350.00

RBT Boddy - Furnace 760-5616- 381010 200.00

RBT Boddy - Furnace fan 760- 5616- 381010 50.00

Vendor R01183 - BODDY, JERRY Total: 600.00

Gas marking pills 710-141001 393. 29

4" IPS mechanical coupling 710-141001 318.58

Elbows, caps, LBC -4 710-141001 5, 801.56

4" IPS mechanical couplings 710-141001 917. 82

Equipment locks 710- 141001 227. 23

Misc. electric items 710- 141001 1, 030.24

Vendor 109500 - BORDER STATES ELECTRIC SUPPLY Total: 8, 688.72

RBT Bregel - LED lighting 760-5616-381023 20.97

Vendor 112660 - BREGEL, HEATHER Total: 20.97

RBT Brownfield - Dishwasher 760-5616-381501 25. 00

Vendor 915828 - BROWNFIELD, SHEILA Total: 25. 00

RBT Carda - Dishwasher 760-5616- 381501 25. 00

Vendor 916852 - CARDA, LELONNIE M. Total: 25. 00

Rebar, tie wire, nail stake 710-5577- 530202 54. 73

Hot roll, nail stake 710-5573- 222005 33. 15

Vendor 158100 - CARROLL DISTRIBUTING & CONSTR SUPPLY INC Total: 87. 88

ball valve, gasket 750- 5553- 222010 1, 078.00

Vendor 158400 - CARTER PUMP LLC Total: 1, 078.00

UG Conversion 710- 5577- 530204 307. 05

UG Conversion 710- 5577-530204 342.48

Vendor 160000 - CB ELECTRIC INC Total: 649.53

Forklift gas 760- 5621- 221010 28. 50

Vendor 162300 - CENTRAL REGION COOPERATIVE Total: 28.50

Supplies 720-5573- 222005 2. 76

Supplies 740-5573- 222005 24. 85

Vendor 181350 - COBORN' S INC Total: 27. 61

Internet 07/ 20/ 18 - 08/ 19/ 18 765- 5591- 332100 134. 85

Vendor 183670 - COMCAST Total: 134.85

VOIP Phone System 760-5597- 550010 2, 374. 50

Vendor 187600 - COMPUTER TECHNOLOGY SOLUTIONS INC. Total: 2, 374. 50

1" water pipe 710-141001 353. 53

Lid covers, valve box risers 710- 141001 977. 94

Vendor 316125 - CORE & MAIN LP Total: 1, 331.47

CCR Drinking Water Report 740-5591- 332100 1, 429. 76

Vendor 197950 - CORPORATE GRAPHICS COMMERCIAL Total: 1, 429. 76

7>>I912018 12: 4..',:47 PM Page 2 of 17


Vendor Name Payable Number Post Date

Vendor: 226050 - DAKOTA SUPPLY GROUP INC

DAKOTA SUPPLY GROUP INC D944151 07/ 19/ 2018

Vendor: R00380 - DITTRICH, SHERI

DITTRICH, SHERI RBT 7/ 2018 07/ 19/ 2018

Vendor: 921910- DOMEIER, RANDY

DOMEIER, RANDY RBT 7/ 2018 07/ 19/ 2018

Vendor: 238990 - DUNCAN CO

FASTENALCOMPANY MNNEW153779

DUNCAN CO 3003112 07/ 19/ 2018

Vendor: 254750 - ENERGY ECONOMIC INC

FASTENALCOMPANY

ENERGY ECONOMIC INC 43150 07/ 19/ 2018

ENERGY ECONOMIC INC 43263 07/ 19/ 2018

Vendor: 255000 - ENERGY EDUCATION COUNCIL

FASTENALCOMPANY

ENERGY EDUCATION COUNCI 1561 07/ 19/ 2018

ENERGY EDUCATION COUNCI 1561 07/ 19/ 2018

Vendor: 256792 - ENVIRONMENTAL SYSTEMS RESEARCH INST

ENVIRONMENTAL SYSTEMS R 93487890 07/ 19/ 2018

ENVIRONMENTAL SYSTEMS 93487890 07/ 19/ 2018

Vendor: 267325 - FASTENAL COMPANY





FASTENAL COMPANY MNNEW154206


FASTENAL COMPANY MNNEW154509







FASTENALCOMPANY MNNEWlSS4431

Vendor: 267400 - FASTRAK SOFTWORKS, INC

FASTRAK SOFTWORKS, INC 20371

Vendor: 269750 - FERGUSON ENTERPRISES INC # 1657

FERGUSON ENTERPRISES INC 5656710- 3

FERGUSON ENTERPRISES INC 5771934



FERGUSON ENTERPRISES INC 5786817- 1



Post Dates: - 07/ 19/ 2018

Description ( Item) Account Number Amount

Water fittings 710-141001 254. 84

Vendor 226050 - DAKOTA SUPPLY GROUP INC Total: 254. 84

RBT Dittrich - Thermostat 760- 5616-381015 20. 00

Vendor R00380 - DITTRICH, SHERI Total: 20.00

RBT Domeier - Room AC 760- 5616-381501 25. 00

Vendor 921910 - DOMEIER, RANDY Total: 25. 00

Pressure switch 710-5513- 222357 351. 78

Vendor 238990 - DUNCAN CO Total: 351. 78

Cadweld charges 730-5573- 222140 285. 64

17# anodes 710- 141001 2, 680.59

Vendor 254750 - ENERGY ECONOMIC INC Total: 2,966.23

2018 membership 710-5591-347040

2018 membership 760-5616-347040

Vendor 255000 - ENERGY EDUCATION COUNCIL Total:

ESRI Software Maitenance Re 760-5641- 347040

ESRI Software Maitenance Re 760-5641- 350010

Vendor 256792 - ENVIRONMENTAL SYSTEMS RESEARCH INSTTotal:

07/ 19/ 2018 repair milwaukee tool 710-5573- 222001

07/ 19/ 2018 AA, AAA, D batteries 710-141001

07/ 19/ 2018 misc hardware, sawzall blades 750-5553-222001

07/ 19/ 2018 Screws, nuts, washers 710-141001

07/ 19/ 2018 Gas meter paint 710-141001

07/ 19/ 2018 storage cabinet 710-5511- 221208

07/ 19/ 2018 C" batteries 710- 141001

07/ 19/ 2018 mist hardware 750-5553-222010

07/ 19/ 2018 spray paint, drill bit 710-5513- 222001

07/ 19/ 2018 rings 710-5513- 222351

07/ 19/ 2018 Cotton rags 710- 141001

07/ 19/ 2018 cutter wheels 710-5513- 222001

07/ 19/ 2018 Band saw blade 710-5513- 222001

07/ 19/ 2018 safety glasses 750-5551-221150

Vendor 267325 - FASTENAL COMPANY Total:

07/ 19/ 2018 Annual Support agreementfo 710-5513- 222357

Vendor 267400 - FASTRAK SOFTWORKS, INC Total:

07/ 19/ 2018 2" ball valves 710-141001

07/ 19/ 2018 12" PVC pipe, elbows 710- 141001

07/ 19/ 2018 2" pipe & fittings 710- 141001

07/ 19/ 2018 Pipe fittings 710- 141001

07/ 19/ 2018 Pipe fitting 710- 141001

07/ 19/ 2018 6" 90degree elbows 720-5573- 222145

07/ 19/ 2018 Pipe fittings 710-141001

Vendor 269750 - FERGUSON ENTERPRISES INC # 1657 Total:

Vendor: 269754 - FERGUSON WATERWORKS

FERGUSON WATERWORKS 0287091 07/ 19/ 2018

FERGUSON WATERWORKS 0288714 07/ 19/ 2018

382. 50

382. 50

765. 00

10,430.58

89.42

10,520.00

15. 80

112. 61

159. 83

76. 15

198.00

372. 95

37. 16

65. 55

37. 69

3. 00

211. 55

50.45

34.63

iom

1, 420.00

1,420.00

342. 16

837. 28

518.76

363. 74

17. 12

182. 87

47.99

2, 309.92

Couplings, stiffeners 710-141001 810.41

EZ Valve Grease 740-5573- 222001 379. 31

Vendor 269754 - FERGUSON WATERWORKS Total: 1, 189. 72

7/ t9! 2018 ', 2: 43: 47 PM Paye 3 of 17

Expense Approval Report Post Dates: - 07/ 19/ 2018

Vendor Name Payable Number Post Date Description ikem) Account Number Amount

Vendor: 000418 - FISCHER, DARYLE W.

FISCHER, DARYLE W. RBT 7/ 2018. 1 07/ 19/ 2018 RBT Fischer- Central AC 760- 5616-381012 350.00

FISCHER, DARYLE W. RBT 7/ 2018. 2 07/ 19/ 2018 RBT Fischer- Furnace 760- 5616- 381010 200.00

FISCHER, DARYLE W. RBT 7/ 2018. 2 07/ 19/ 2018 RBT Fischer - Furnace fan 760- 5616- 381010 50.00

Vendor 000418 - FISCHER, DARYLE W. Total: 600.00

Vendor: R00767 - FLECK, LISA or TONY

FLECK, LISA or TONY RBT 7/ 2018 07/ 19/ 2018 RBT Fleck - Water heater 76D- 5616- 381040 75. 00

Vendor R00767 - FLECK, LISA or TONY Total: 75. 00

Vendor: 280420- FRONTIER PRECISION INC

FRONTIER PRECISION INC 176830 07/ 19/ 2018 Rental of Trimble Geo - GPS r 740-5571- 331400 1,400.00

Vendor 280420 - FRONTIER PRECISION INC Total: 1, 400.00

Vendor: 283250 - FVB ENERGY INC

FVB ENERGY INC INV -0178 07/ 19/ 2018 Engineering svcs. high- pressur 720- 5577- 530322 18, 940.00

Vendor 283250 - FVB ENERGY INC Total: 18, 940.00

Vendor: 286000 - GAG SHEET METAL INC

GAG SHEET METAL INC 40458 07/ 19/ 2018 Replaced thermostat on cond 710-5513- 222005 295.63

Vendor 286000 - GAG SHEET METAL INC Total: 295.63

Vendor: 930814 - GEISTFELD, LOU

GEISTFELD, LOU RBT 7/ 2018 07/ 19/ 2018 RBT Geistfeld - Central AC 760-5616-381012 275. 00

Vendor 930814 - GEISTFELD, LOU Total: 275.00

Vendor: R01253 - GISLASON & HUNTER LLP

GISLASON & HUNTER LLP RBT-07/ 2018 07/ 19/ 2018 RBT GISLASON & HUNTER -HI 760-5616-381022 1, 668.30

Vendor R01253 - GISLASON & HUNTER LLP Total: 1, 668.30

Vendor: 295100 - GOPHER STATE ONE -CALL INC

GOPHER STATE ONE -CALL INC 8061200 07/ 19/ 2018 June locates 710-5591- 225310 84.04

GOPHER STATE ONE -CALL INC 8061200 07/ 19/ 2018 June locates 710-5591-332100 84. 04

GOPHER STATE ONE -CALL INC 8061200 07/ 19/ 2018 June locates 730-5591-332100 84.04

GOPHER STATE ONE -CALL INC 8061200 07/ 19/ 2018 June locates 740-5591-332100 84.03

Vendor 295100 - GOPHER STATE ONE -CALL INC Total: 336. 15

Vendor: 296200 - GOVDEALS INC

GOVDEALS INC 8513- 062018 07/ 19/ 2018 Auction Fee - 2000 JD F911 M 730-5591- 332100 120. 00

Vendor 296200 - GOVDEALS INC Total: 120.00

Vendor: 296560 - GRAINGER INC

GRAINGER INC 9845758896 07/ 19/ 2018 PVC pipe 710-5513- 222351 209. 25

Vendor 296560 - GRAINGER INC Total: 209. 25

Vendor: 297250 - GRAPHIC CONTROLS LLC

GRAPHIC CONTROLS LLC NE6264 07/ 19/ 2018 Gas recording charts 710- 141001 283. 53

Vendor 297250 - GRAPHIC CONTROLS LLC Total: 283. 53

Vendor: 297500 - GRAYBAR ELECTRIC COMPANY INC

GRAYBAR ELECTRIC COMPAN 9304762228 07/ 19/ 2018 Fuses, 4" end caps 710- 141001 328.17

GRAYBAR ELECTRIC COMPAN 9304794482 07/ 19/ 2018 Fuses, entrance heads, hub pl 710-141001 2, 241.54

GRAYBAR ELECTRIC COM PAN 9304820526 07/ 19/ 2018 1- 1/ 2" PVC elbows 710-141001 216.10

GRAYBAR ELECTRIC COM PAN 9304845846 07/ 19/ 2018 4" couplings 710- 141001 409.76

GRAYBAR ELECTRIC COMPAN 9304914624 07/ 19/ 2018 2S meter sockets 710-141001 1, 359.07

Vendor 297500 - GRAYBAR ELECTRIC COMPANY INC Total: 4,554.64

Vendor: 299600- GROEBNER & ASSOCIATES INC

GROEBNER & ASSOCIATES IN 361542 07/ 19/ 2018 Gas tracer wire connectors 710- 141001 339.15

GROEBNER & ASSOCIATES IN 361869 07/ 19/ 2018 Blue tracer wire 710- 141001 334.47

GROEBNER & ASSOCIATES IN 362389 07/ 19/ 2018 Direct bury tracer lugs 710-141001 283. 38

GROEBNER & ASSOCIATES IN 362452 07/ 19/ 2018 2"- 4" riser brackets 710- 141001 400.08

GROEBNER & ASSOCIATES IN 362815 07/ 19/ 2018 Laser remote gas leak detecto 730-5577-550020 8, 930.00

GROEBNER & ASSOCIATES IN 362815 07/ 19/ 2018 Shipping and sales tax 730-5577-550020 644.50

GROEBNER & ASSOCIATES IN 363106 07/ 19/ 2018 7" prefab meter bars 710-141001 3, 176. 07

Vendor 299600 - GROEBNER & ASSOCIATES INC Total: 14, 107.65

7/ 14+/ 2018 12: 43: 47 PM Paye 4 of 17


Vendor Name Payable Number Post Date Description ( Item) Account Number Amount

Vendor: R02254 - GRUBBS, MICHELLE

GRUBBS, MICHELLE RBT- 07/ 2018 07/ 19/ 2018 RBTGRIBBS - AC 760-5616-381012 275. 00

Vendor R01254 - GRUBBS, MICHELLE Total: 275. 00

Vendor: 308890- H & M DRILLING INC

H & M DRILLING INC 1383 07/ 19/ 2018 Kraft Foods/ Precision Tool - D 710-5577-530202 4, 640.00

H & M DRILLING INC 1384 07/ 19/ 2018 Directional drill - precision to 710-5577-530202 1, 250.00

H & M DRILLING INC 1385 07/ 19/ 2018 Direction drill - precision tool 710-5577-530202 1, 000.00

H & M DRILLING INC 1386 07/ 19/ 2018 Directional drill - 209 S State 710-5577-530202 912. 50

H & M DRILLING INC 1408 07/ 19/ 2018 St. Paul School Expansion 710-5577-530202 3, 880.00

Vendor 308890 - H & M DRILLING INC Total: 11, 682.50

Vendor: 311000 - HACH COMPANY

HACH COMPANY 11022262 07/ 19/ 2018 Water Testing Supplies 740-5511- 226010 657.88

HACH COMPANY 11024487 07/ 19/ 2018 Water Testing Supplies 740-5511- 226010 72. 49

Vendor 311000- HACH COMPANY Total: 730.37

Vendor: 314425 - HASTINGS FIBER GLASS PRODUCTS INC

HASTINGS FIBERGLASS PROD 542554- 1 07/ 19/ 2018 Repair fluke meter 710-5573- 222001 223.75

Vendor 314425 - HASTINGS FIBER GLASS PRODUCTS INC Total: 223.75

Vendor: 315750- HAWKINS INC

HAWKINS INC 4303831 07/ 19/ 2018 Sodium Permanganate 740-141030 5, 753.98

HAWKINS INC 4306683 07/ 19/ 2018 chlorine 750-5551-221100 620.88

HAWKINS INC 4309290 07/ 19/ 2018 Chlorine 740-141030 620.88

HAWKINS INC 4314646 07/ 19/ 2018 sulfur dioxide 750-5551- 221100 1, 661.50

HAWKINS INC 4314670 07/ 19/ 2018 Hydrofluosilicic Acid 740-141030 3,019.59

HAWKINS INC 4320221 07/ 19/ 2018 Sodium Permanganate 740- 141030 5, 773.48

Vendor 315750- HAWKINS INCTotal: 17,450.31

Vendor: R01255 - HENN, LOWELL

HENN, LOWELL RBT-07/ 2018 07/ 19/ 2018 RBT HENN - REFRIG. 760- 5616- 381501 30.00

Vendor R01255- HENN, LOWELL Total: 30.00

Vendor: 324500- HOFFMAN CONSTRUCTION INC

HOFFMAN CONSTRUCTION IN 0058583 07/ 19/ 2018 Class 5 rock - 1326 S. Franklin 740- 5573- 222145 108.08

HOFFMAN CONSTRUCTION IN 0058592 07/ 19/ 2018 Sand/ Class 5 - 304 South Stat 740- 5573- 222145 166.20

HOFFMAN CONSTRUCTION IN 0058625 07/ 19/ 2018 Class 5 740- 5573- 222145 210.15

HOFFMAN CONSTRUCTION IN 0058747 07/ 19/ 2018 Sand/ Class 5 - 905 North Ger 740- 5573- 222145 716. 81

HOFFMAN CONSTRUCTION IN 0058788 07/ 19/ 2018 Kasota stone/ sand/ Class 5 - 1 740- 5573- 222145 785.44

HOFFMAN CONSTRUCTION IN 0058801 07/ 19/ 2018 Sand - 1326 North Payne 740-5573- 222145 440.43

HOFFMAN CONSTRUCTION IN 30451 07/ 19/ 2018 Concrete - WO #36802 730-5573- 222140 25. 04

HOFFMAN CONSTRUCTION IN 30461 07/ 19/ 2018 Demo - concrete 740-5573- 222145 19. 95

HOFFMAN CONSTRUCTION IN 30464 07/ 19/ 2018 Demo concrete 740-5573- 222145 66.47

HOFFMAN CONSTRUCTION IN 30467 07/ 19/ 2018 Demo concrete 710-5577- 530202 27. 78

HOFFMAN CONSTRUCTION IN 30477 07/ 19/ 2018 demo concrete 710-5577- 530202 14. 91



HOFFMAN CONSTRUCTION IN 30487 07/ 19/ 2018 Demo pallets 710-5513- 222005 32.00

HOFFMAN CONSTRUCTION IN 30992 07/ 19/ 2018 demo wood spools 710-5573- 222305 126. 00

HOFFMAN CONSTRUCTION IN 58604 07/ 19/ 2018 Class 5 - WO #36819 730-5573- 222140 159. 25

HOFFMAN CONSTRUCTION IN 58605 07/ 19/ 2018 black dirt, limestone 710-5577- 530202 170. 80

HOFFMAN CONSTRUCTION IN 58619 07/ 19/ 2018 limestone 710-5577- 530202 56. 56



HOFFMAN CONSTRUCTION IN 58750 07/ 19/ 2018 Limestone 710-5577- 530202 266. 24

HOFFMAN CONSTRUCTION IN 58757 07/ 19/ 2018 Redstone 710-5573- 222305 80.67

HOFFMAN CONSTRUCTION IN 58759 07/ 19/ 2018 Blackdirt, redstone 71D- 5573- 222305 124. 66

HOFFMAN CONSTRUCTION IN 58761 07/ 19/ 2018 Redstone & Class 5 for border 730- 5573- 222005 288.91

HOFFMAN CONSTRUCTION IN 58772 07/ 19/ 2018 Limestorne 710- 5573- 222305 205. 88

HOFFMAN CONSTRUCTION IN 58785 07/ 19/ 2018 redstone, sand 710-5577- 530202 269. 19

HOFFMAN CONSTRUCTION IN 58800 07/ 19/ 2018 Sand 710-5577- 530202 78.29

HOFFMAN CONSTRUCTION IN 58828 07/ 19/ 2018 redstone, limestone, sand, cla 710-5577- 530202 182.77

HOFFMAN CONSTRUCTION IN 58834 07/ 19/ 2018 Class 5 710-5573- 222305 33. 99

7/ 19/ 2018 12: 43: 47 PPM Paye S of 17

Expense Approval Report Post Dates: 07/ 19/ 2018


HOFFMAN CONSTRUCTION IN 83129 07/ 19/ 2018 screened black dirt 750-5553- 222008 99.00

HOFFMAN CONSTRUCTION IN 83195 07/ 19/ 2018 Track skidsteer 710-5577-530202 110.00

Vendor 324500 - HOFFMAN CONSTRUCTION INC Total: 5, 623. 86

Vendor: 935542 - HOFMEISTER, DENNIS

HOFMEISTER, DENNIS RBT 7/ 2018 07/ 19/ 2018 RBTHofineister- Thermostat 760-5616-381015 20.00

Vendor 935542 - HOFMEISTER, DENNIS Total: 20.00

Vendor: 344635 - IRBY TOOL AND SAFETY

IRBY TOOL AND SAFETY S010794610. 001 07/ 19/ 2018 Purchase fluke meter 710-5573- 222001 712. 27

IRBY TOOL AND SAFETY S010805524. 001 07/ 19/ 2018 1/ 0 SOL wire 710- 141001 20,184.07

IRBY TOOL AND SAFETY S010807387.001 07/ 19/ 2018 350THHNwire 710-141001 3, 894.34

IRBY TOOL AND SAFETY 5010807387. 003 07/ 19/ 2018 500 MCM wire 710- 141001 22, 229. 13

IRBY TOOL AND SAFETY 5010812875. 001 07/ 19/ 2018 Hard hats 710-5571- 221150 161. 11

IRBY TOOL AND SAFETY 5010826651.001 07/ 19/ 2018 1/ 0 SOL Alum wire 710-141001 6, 897.35

IRBY TOOL AND SAFETY 5010826651.002 07/ 19/ 2018 Credit for returned wire 710-141001 6, 897. 35

IRBY TOOL AND SAFETY 5010826651.003 07/ 19/ 2018 1/ 0 SOL Alum wire 710-141001 6, 847.55

IRBY TOOL AND SAFETY 5010840465. 001 07/ 19/ 2018 Feed thru standoff bushings 710-141001 527. 17

IRBY TOOL AND SAFETY 5010841801.001 07/ 19/ 2018 fuse link 710-5573-222320 63. 59

Vendor 344635 - IRBY TOOL AND SAFETY Total: 54,619.23

Vendor: R01256 - JOHNSON, JOE

JOHNSON, JOE RBT-07/ 2018 07/ 19/ 2018 RBT JOHNSON - REFRIG.& DIS 760-5616-381501 55. 00

Vendor R01256 - JOHNSON, JOE Total: 55.00

Vendor: 355050 - JORDAN TRANSFORMER, LLC

JORDAN TRANSFORMER, LLC 14524 07/ 19/ 2018 Inspection of LTC on transfore 710-5513- 222351 7,454.00

Vendor 355050 - JORDAN TRANSFORMER, LLC Total: 7,454.00

Vendor: 355200- JOURNALTHE

JOURNAL THE 004971 07/ 19/ 2018 Ad - Programmable thermost 760-5616-381015 56. 00

JOURNAL THE 004971 07/ 19/ 2018 Ad - ACC& C 760-5616-381018 56. 00

JOURNALTHE INV0009795 07/ 19/ 2018 Ad Relief Boiler Operator 710-5591-332100 304.20

Vendor 355200 - JOURNAL THE Total: 416.20

Vendor: 355550 - JP PLUMBING AND HEATING

1P PLUMBING AND HEATING 64236 07/ 19/ 2018 RBTJP Plumbing - ( 1) AC C& C 760-5616- 381018 40.00

Vendor 355550 - 1P PLUMBING AND HEATING Total: 40.00

Vendor: 355600 - JT SERVICES OF MINNESOTA

1T SERVICES OF MINNESOTA JT18- 166- 02 07/ 19/ 2018 Double mast arms 710- 141001 5, 605. 00

JT SERVICES OF MINNESOTA JT18- 170-03 07/ 19/ 2018 2' street light arms 710- 141001 5, 610.00

JT SERVICES OF MINNESOTA JT18-178-01 07/ 19/ 2018 3" innerduct 710- 141001 2, 618.44

IT SERVICES OF MINNESOTA JT18- 178- 08 07/ 19/ 2018 Gas flat markers 710- 141001 576. 06

JT SERVICES OF MINNESOTA JT18- 178- 16 07/ 19/ 2018 10" arms for street light poles 710- 141001 340.00

JT SERVICES OF MINNESOTA JT18- 179- 04 07/ 19/ 2018 Secondary cabinets 710- 141001 25, 019.44

JT SERVICES OF MINNESOTA JT18- 183- 02 07/ 19/ 2018 74W LED fixtures 710- 141001 548. 25

IT SERVICES OF MINNESOTA JT18- 183- 03 07/ 19/ 2018 LED photocontrols 710- 141001 1, 112. 50

IT SERVICES OF MINNESOTA JT18- 184- 03 07/ 19/ 2018 4" direct bore conduit 710- 141001 5,482.69

IT SERVICES OF MINNESOTA JT18- 184-04 07/ 19/ 2018 4" innerduct 710-141001 2, 364.61

JT SERVICES OF MINNESOTA JT18- 190-05 07/ 19/ 2018 3" eloc' s 710-141001 243. 14

IT SERVICES OF MINNESOTA JT18- 193- 08 07/ 19/ 2018 Wire pulling lube 710-141001 794.30

Vendor 355600- 1T SERVICES OF MINNESOTA Total: 50,314.43

Vendor: 375250 - KEMSKE PAPER COMPANY

KEMSKE PAPER COMPANY 296900 07/ 19/ 2018 pens, flash drives, toner cartri 750- 5591- 220010 555. 57

KEMSKE PAPER COMPANY 298487 07/ 19/ 2018 pens 750-5591-220010 34. 29

KEMSKE PAPER COMPANY 298583 07/ 19/ 2018 Pen refills, envelopes 760-5591- 220010 14. 19

KEMSKE PAPER COMPANY 298666 07/ 19/ 2018 business card sleeves 710-5591- 220010 8. 21

KEMSKE PAPER COMPANY 298698 07/ 19/ 2018 office supplies 720-5591-220010 8. 03

KEMSKE PAPER COMPANY 298698 07/ 19/ 2018 office supplies 740-5591- 220010 72. 23

KEMSKE PAPER COMPANY 298704 07/ 19/ 2018 Notebooks, post -its, pencils 760-5591- 220010 41.31

KEMSKE PAPER COMPANY 298794 07/ 19/ 2018 Printer toner - Metering 760-5583- 222001 79. 98

KEMSKE PAPER COMPANY 298831 07/ 19/ 2018 Service application forms 710-5591-220010 55. 27

KEMSKE PAPER COMPANY 298831 07/ 19/ 2018 Service application forms 730-5571-226010 55. 26

KEMSKE PAPER COMPANY 298831 07/ 19/ 2018 Service application forms 740-5573- 222135 55. 26

7/ 19/ 2615 12: 413: 47 Pf4 Paye 5 of 17


Vendor Name Payable Number Post Date Description ( Rem) Account Number Amount

KEMSKE PAPER COMPANY 298919 07/ 19/ 2018 Printer ink, pens, post -its 760-5621- 220010 199. 38

KEMSKE PAPER COMPANY 298979 07/ 19/ 2018 Page marker flags 760-5591- 220010 13. 18

Vendor 375250- KEMSKE PAPER COMPANY Total: 1, 192.16

Vendor: 000276 - KIBBLE EQUIPMENT

KIBBLE EQUIPMENT 1442914 07/ 19/ 2018 Switch for #770 Backhoe 730-5573- 222001 63. 29

Vendor 000276- KIBBLE EQUIPMENT Total: 63. 29

Vendor: 378500- KLASSEN MECHANICAL INC

KLASSEN MECHANICAL INC 74361 07/ 19/ 2018 Front Conference Room AC u 760-5593- 222005 120.00

KLASSEN MECHANICAL INC 74430 07/ 19/ 2018 asco solenoid valve 750-5573- 222455 248. 17

KLASSEN MECHANICAL INC 74433 07/ 19/ 2018 pvc sewer cap 750-5573-222455 11.73

KLASSEN MECHANICAL INC 74457 07/ 19/ 2018 RBT Klassen - ( 13) AC C& C 760-5616-381018 520.00

Vendor 378500 - KLASSEN MECHANICAL INC Total: 899.90

Vendor: 382341- KOHLS WEELBORG CHEVROLET LLC

KOHLS WEELBORG CHEVROLE 76318 07/ 19/ 2018 Service chargei 710-5571-222025 89.95

Vendor 382341- KOHLS WEELBORG CHEVROLET LLC Total: 89.95

Vendor: 383800 - KRAFT HEINZ FOODS COMPANY

KRAFT HEINZ FOODS COMPA RBT 7/ 2018 07/ 19/ 2018 RBT Kraft- High efficiency ligh 760-5616-381022 4, 983.00

Vendor 383800 - KRAFT HEINZ FOODS COMPANY Total: 4,983.00

Vendor: 384070 - KRAL CONCRETE & CONSTRUCTION, INC.

KRAL CONCRETE & CONSTRU INV0009792 07/ 19/ 2018 sidewalks & curbs 740-5573- 222140 3, 792.00

KRAL CONCRETE & CONSTRU INV0009792 07/ 19/ 2018 sidewalks & curbs 740-5573-222145 7, 504.00

Vendor 384070 - KRAL CONCRETE CONSTRUCTION, INC. Total: 11,296.00

Vendor: 402230 - LIND HOUSE ASSOCIATION

LIND HOUSE ASSOCIATION RBT 7/ 2018 07/ 19/ 2018 RBT Lind House - Central AC 760-5616-381012 275.00

Vendor 402230 - LIND HOUSE ASSOCIATION Total: 275.00

Vendor: 404250 - LOCATORS & SUPPLIES INC

LOCATORS & SUPPLIES INC 0267138 -IN 07/ 19/ 2018 Locate paint 710-141001 185. 58

LOCATORS & SUPPLIES INC 0267200 -IN 07/ 19/ 2018 14" drain spade 710-141001 128. 14

LOCATORS & SUPPLIES INC 0267334 -IN 07/ 19/ 2018 Gas marking paint 710-141001 185. 66

LOCATORS & SUPPLIES INC 0267563 -IN 07/ 19/ 2018 Red locate paint 710-141001 193. 66

Vendor 404250 - LOCATORS & SUPPLIES INC Total: 693.04

Vendor: R012S7 - LOOP, MARK

LOOP, MARK RBT- 07/ 2018 07/ 19/ 2018 RBT LOOP - AC 760-5616- 381012 275.00

Vendor R01257 - LOOP, MARK Total: 275.00

Vendor: 405500 - LUEPKE OIL & TRUCKING LLC

LUEPKE OIL & TRUCKING LLC 14738 07/ 19/ 2018 prem. gas 750-5551- 221050 113. 65

LUEPKE OIL & TRUCKING LLC 14887 07/ 19/ 2018 Super Unleaded Gasoline #90 720-5571- 222025 5. 00



LUEPKE OIL & TRUCKING LLC 14972 07/ 19/ 2018 Super Unleaded Gasoline #94 740-5571-222025 61. 84



LUEPKE OIL & TRUCKING LLC 15103 07/ 19/ 2018 Super Unliaded Gasoline - #94 720-5571- 222025 7. 00

LUEPKE OIL & TRUCKING LLC 15103 07/ 19/ 2018 Super Unliaded Gasoline - #94 740-5571-222025 63. 00

Vendor 405500 - LUEPKE OIL & TRUCKING LLC Total: 363.89

Vendor: 484550 - M R PAVING & EXCAVATING INC

M R PAVING & EXCAVATING 1 35097 07/ 19/ 2018 Multiple patches 710-5577- 530202 2, 274.52

M R PAVING & EXCAVATING 1 35181 07/ 19/ 2018 Alley patching at 115 South M 710-5577- 530202 406.02

M R PAVING & EXCAVATING 1 35181 07/ 19/ 2018 Alley patching at 115 South M 730-5573- 222140 203.01

M R PAVING & EXCAVATING 1 35434 07/ 19/ 2018 Various Patching 740-5573- 222140 1, 818.00

M R PAVING & EXCAVATING 1 35434 07/ 19/ 2018 Various Patching 740-5573- 222140 2, 866.38

M R PAVING & EXCAVATING 1 35434 07/ 19/ 2018 Various Patching 740-5573- 222145 2, 121. 00

M R PAVING & EXCAVATING 1 35434 07/ 19/ 2018 Various Patching 740-5573- 222145 4,444.00

M R PAVING & EXCAVATING 1 35562 07/ 19/ 2018 Various Patches 740-5573- 222140 2, 018.99

M R PAVING & EXCAVATING 1 35562 07/ 19/ 2018 Various Patches 740-5573- 222145 1, 799. 82

Vendor 484550 - M R PAVING & EXCAVATING INC Total: 17, 951. 74

7/ 1. 9/ 201%3 12: 43: 47 PM Page 7 of 17


Vendor Name Payable Number

Vendor: 414240 - MADSEN INK

MADSEN INK PUC 7- 6- 18

MADSEN INK PUC 7- 6- 18

Vendor: 425510 - MARCO TECHNOLOGIES, LLC

Post Date

07/ 19/ 2018

07/ 19/ 2018

Post Dates: - 07/ 19/ 2018

Description ( item) Account Number Amount

Meetings, summer newsletter 760-5601- 332100 700.00

Powerfacts, radio ads 760- 5616- 388901 70.00

Vendor 414240 - MADSEN INK Total: 770.00

MARCO TECHNOLOGIES, LLC INV5329196 07/ 19/ 2018 Contract 6/ 17/ 18 to 7/ 16/ 18 720- 5593- 224001 2. 55

MARCO TECHNOLOGIES, LLC INV5329196 07/ 19/ 2018 Contract 6/ 17/ 18 to 7/ 16/ 18 740- 5593- 224001 22. 92

MARCO TECHNOLOGIES, LLC INV5334357 07/ 19/ 2018 services 05/ 21/ 18- 06/ 20/ 18 765- 5591- 347113 866.40

MARCO TECHNOLOGIES, LLC INV5358212 07/ 19/ 2018 Overage charge 720-5593- 224001 7. 79

MARCO TECHNOLOGIES, LLC INV5358212 07/ 19/ 2018 Overage charge 740- 5593- 224001 70. 10

Vendor 425510 - MARCO TECHNOLOGIES, LLC Total: 969. 76

Vendor: R01258 - MARTI, KATE

MARTI, KATE RBT- 07/ 2018 07/ 19/ 2018 RBT MARTI - AC 760-5616- 381012 350.00

MARTI, KATE RBT- 07/ 2018- 1 07/ 19/ 2018 RBT MARTI - FURNACE & VSD 760-5616- 381010 250.00

Vendor R01258 - MARTI, KATE Total: 600.00

Vendor: 435500 - MATHIOWETZ ENTERPRISES INC

MATHIOWETZ ENTERPRISES 1 205045 07/ 19/ 2018 Credit for double pymt. 710-5513- 222350 23.40

MATHIOWETZ ENTERPRISES 1 452 07/ 19/ 2018 Disposal charges 750-5553- 222010 1, 193. 69

Vendor 435500 - MATHIOWETZ ENTERPRISES INC Total: 1, 170.29

Vendor: 443500 - MCMASTER- CARR SUPPLY COMPANY

MCMASTER- CARR SUPPLY CO 65198871 07/ 19/ 2018 Threaded pipe fittings 710-5513- 222350 28.98

MCMASTER- CARR SUPPLY CO 66165820 07/ 19/ 2018 Pipe sealant tape 710-141001 54.46

MCMASTER- CARR SUPPLY CO 66742061 07/ 19/ 2018 Pressure gauges 710- 141001 81. 18

Vendor 443500 - MCMASTER- CARR SUPPLY COMPANY Total: 164.62

Vendor: 444840 - MEDTOX LABORATORIES INC

MEDTOX LABORATORIES INC 0620184429 07/ 19/ 2018 July Drug Testing 710- 5591- 331601 100. 04

MEDTOX LABORATORIES INC 0620184429 07/ 19/ 2018 July Drug Testing 730- 5591- 331601 50.02

MEDTOX LABORATORIES INC 0620184429 07/ 19/ 2018 July Drug Testing 750- 5591- 331601 50.02

Vendor 444840 - MEDTOX LABORATORIES INC Total: 200.08

Vendor: 000202 - MENARDS - NEW ULM

MENARDS - NEW ULM 00549 07/ 19/ 2018 Snap coupler 710-5573-222001 1. 19

MENARDS - NEW ULM 01041 07/ 19/ 2018 T8 LED lights PUC Admin. stair 760-5593-222005 38.97

MENARDS - NEW ULM 01210 07/ 19/ 2018 bags, plugs, std cnctr 750-5551- 226010 52. 34

MENARDS- NEW ULM 01258 07/ 19/ 2018 Cooler 710-5573- 222001 29.97

MENARDS- NEW ULM 01799 07/ 19/ 2018 supplies 765- 5593-222001 80.39

MENARDS - NEW ULM 1276 07/ 19/ 2018 Screws, trash bags, degreaser 710-141001 113. 82

MENARDS - NEW ULM 1276 07/ 19/ 2018 Small propane tank 710-5573- 222001 8. 97

MENARDS- NEW ULM 1276 07/ 19/ 2018 Wiper fluid additive 760-5621-221010 4.97

MENARDS- NEWULM 1595 07/ 19/ 2018 Chip brushes 710-141001 51.15

MENARDS - NEW ULM 1812 07/ 19/ 2018 non -shrink grout, impact drill 720-5573- 222140 71.06

MENARDS- NEW ULM 427 07/ 19/ 2018 Drain spade shovels 710- 141001 49.78

MENARDS- NEW ULM 427 07/ 19/ 2018 Mailbox 760-5623- 222005 54. 99

MENARDS- NEW ULM 571 07/ 19/ 2018 Spot, aerosol cleaner 710-5513- 222350 17. 34

MENARDS - NEW ULM 867 07/ 19/ 2018 Interior cleaner, bug spray, sh 710- 141001 53.42

Vendor 000202 - MENARDS - NEW ULM Total: 628.36

Vendor: 000504 - METERING & TECHNOLOGY SOLUTIONS

METERING & TECHNOLOGY S 11949 07/ 19/ 2018 3" Badger Turbo Meter 740-5573- 222135 241. 66

Vendor 000504 - METERING & TECHNOLOGY SOLUTIONS Total: 241.66

Vendor: 459125 - MILTON ROY COMPANY

MILTON ROY COMPANY 3777858 RI 07/ 19/ 2018 Odorizer repair kit 710- 141001 495.57

Vendor 459125 - MILTON ROY COMPANY Total: 495.57

Vendor: 462500 - MMUA

MMUA 51392 07/ 19/ 2018 ED Job Training & Safety Prog 710-5591-333050 1, 200. 00

MMUA 51392 07/ 19/ 2018 Gas Circuit Rider Program 730-5591- 349115 2, 580. 00

MMUA 51392 07/ 19/ 2018 Safety Mgmt. Program July -Se 760-5591-349115 5, 375. 00

MMUA 51486 07/ 19/ 2018 Power delivery program - Sco 710-5591-333050 616.00

Vendor 462500 - MMUA Total: 9, 771.00

7/ 19j2018 ! 2: 43: 47 Pfd Page 8 of 17



Vendor: 951810 - MN VALLEY ACTION COUNCIL

MN VALLEY ACTION COUNCIL RBT 7/ 2018 07/ 19/ 2018 RBT MVAC- Low Income Prog 760-5616-388905 500.00

Vendor 951810 - MN VALLEY ACTION COUNCIL Total: 500.00

Vendor: 476500 - MN VALLEY TESTING LAB

MN VALLEY TESTING LAB 924607 07/ 19/ 2018 Coliform Colilert Tests 740-5511-331325 54. 00

MN VALLEY TESTING LAB 924827 07/ 19/ 2018 Coliform Colilert Tests 740-5511- 331325 25. 00

MN VALLEY TESTING LAB 924845 07/ 19/ 2018 nitrate,nitrogen, solids,pot,so 750-5551- 331325 243. 00

MN VALLEY TESTING LAB 925314 07/ 19/ 2018 Coliform Colilert Tests 740-5511- 331325 54.00

MN VALLEY TESTING LAB 926188 07/ 19/ 2018 water testing service 710-5513- 222357 66. 00

MN VALLEY TESTING LAB 926559 07/ 19/ 2018 Coliform Colilert tests, monthl 740-5511- 331325 59.00

MN VALLEY TESTING LAB 927652 07/ 19/ 2018 coliform colilert tests 740-5511- 331325 54.00

MN VALLEY TESTING LAB 928194 07/ 19/ 2018 coliform colilert tests 740-5511- 331325 25.00

Vendor 476500 - MN VALLEY TESTING LAB Total: 580.00

Vendor: 479900 - MONOPRICE INC

MONOPRICE INC 17742632 07/ 19/ 2018 SUPPLIES 765- 5591- 224100 54.03

Vendor 479900 - MONOPRICE INC Total: 54.03

Vendor: 484680 - MSC INDUSTRIAL SUPPLY CO.

MSC INDUSTRIAL SUPPLY CO. 60175338 07/ 19/ 2018 Lamp credit 710- 141001 209.40

MSC INDUSTRIAL SUPPLY CO. 60214358 07/ 19/ 2018 Credit for missing wheel 710- 141001 17.75

MSC INDUSTRIAL SUPPLY CO. 60783199 07/ 19/ 2018 4" wire wheels 710- 141001 177. 50

MSC INDUSTRIAL SUPPLY CO. 61648279 07/ 19/ 2018 Fluorescent lamps 710- 141001 209.40

MSC INDUSTRIAL SUPPLY CO. 62188509 07/ 19/ 2018 2- 1/ 2" strut straps 710-141001 125. 00

MSC INDUSTRIAL SUPPLY CO. 63585489 07/ 19/ 2018 emergency light battery 710-5513- 222005 8. 53

MSC INDUSTRIAL SUPPLY CO. 64899229 07/ 19/ 2018 Ear plugs 710-5573- 222001 50.83

MSC INDUSTRIAL SUPPLY CO. 64899229 07/ 19/ 2018 Ear plugs 760-5621- 221010 50. 83

MSC INDUSTRIAL SUPPLY CO. 65791379 07/ 19/ 2018 Hard hat sweat bands 710- 141001 67. 20

MSC INDUSTRIAL SUPPLY CO. 66945909 07/ 19/ 2018 Die set for threading machine 730-5573- 222001 157. 95

MSC INDUSTRIAL SUPPLY CO. 69684809 07/ 19/ 2018 Misc. earplugs 760-5621- 221010 91. 62

MSC INDUSTRIAL SUPPLY CO. 70194059 07/ 19/ 2018 Lens cleaner 710- 141001 50.07

MSC INDUSTRIAL SUPPLY CO. C60322849 07/ 19/ 2018 Pipe fittings, fluorescent lamp 710- 141001 253.58

MSC INDUSTRIAL SUPPLY CO. C63058049 07/ 19/ 2018 2" couplings, pressure gauges 710- 141001 98.62

Vendor 484680 - MSC INDUSTRIAL SUPPLY CO. Total: 1, 113.98

Vendor: 485180 - MUELLER WATER PRODUCTS, INC

MUELLER WATER PRODUCTS, 3807307 07/ 19/ 2018 Part for tapping machine 730-5573- 222001 185. 31

Vendor 485180 - MUELLER WATER PRODUCTS, INC Total: 185.31

Vendor: 954060 - MUNSON, DAVE

MUNSON, DAVE RBT 7/ 2018 07/ 19/ 2018 RBT Munson - LED lighting 760-5616-381023 30.00

Vendor 954060 - MUNSON, DAVE Total: 30.00

Vendor: 541100 - NALCO COMPANY

NALCO COMPANY 66925169 07/ 19/ 2018 silica solution 710-5511- 221205 110.33

NALCO COMPANY 66927430 07/ 19/ 2018 Solutions 710-5511- 221200 199.92

Vendor 541100 - NALCO COMPANY Total: 310.25

Vendor: 510275 - NAPA AUTO TRUCK PARTS OF NEW ULM

NAPA AUTO & TRUCK PARTS 558154 07/ 19/ 2018 Mirror for Ranger 730-5571- 222025 12.88

NAPA AUTO & TRUCK PARTS 559399 07/ 19/ 2018 lacquer thinner 750-5553- 222010 32.99

NAPA AUTO & TRUCK PARTS 559560 07/ 19/ 2018 Oil filter & oil for Ranger 730-5571- 222025 23. 14

Vendor 510275 - NAPA AUTO & TRUCK PARTS OF NEW ULM Total: 69.01

Vendor: 513950 - NCL OF WISCONSIN INC

NCL OF WISCONSIN INC 408565 07/ 19/ 2018 500ml glass grad cylinders 750-5551- 221110 299.53

Vendor 513950 - NCL OF WISCONSIN INC Total: 299.53

Vendor: 516870 - NEW ULM CITY OF

NEW ULM CITY OF 17270 07/ 19/ 2018 Maintenance truck 10 710-5571- 222025 208.41

NEW ULM CITY OF 17281 07/ 19/ 2018 Maintenance on truck #4 710-5571- 222025 113. 28

NEW ULM CITY OF 17290 07/ 19/ 2018 Service Van # 13 710-5571- 222025 37.61

NEW ULM CITY OF INV0009793 07/ 19/ 2018 Rmb 101- 1000- 113300 Walki 760-5591- 113300 127.50

NEW ULM CITY OF INV0009794 07/ 19/ 2018 Rmb 101- 1000-333050 Boom 760-5591- 333050 35. 00

7/ 19/ 2018 12: 43: 47 PM F -sae 9 of 17



NEW ULM CITY OF JULY2018 07/ 19/ 2018 Rmb101- 1000-330040 Corp r 760-5591- 330040 3, 014.71

Vendor 516870 - NEW ULM CITY OF Total: 3, 536.51

Vendor: 517800 - NEW ULM ELECTRONICS

NEW ULM ELECTRONICS 10107168 07/ 19/ 2018 AC/ DC Adapter for VMD table 730-5573- 222001 9. 97

Vendor 517800 - NEW ULM ELECTRONICS Total: 9. 97

Vendor: 518800 - NEW ULM FURNITURE COMPANY

NEW ULM FURNITURE COMP RBT7/ 2018 07/ 19/ 2018 RBT NU Furniture- High eff. Ii 760-5616- 381022 264. 00

Vendor 518800 - NEW ULM FURNITURE COMPANY Total: 264.00

Vendor: 527000- NILSON HEATING & AIR COND.

NILSON HEATING & AIR COND 29865 07/ 19/ 2018 RBT Nilson - ( 81) AC C& C 760-5616-381018 3, 240.00

NILSON HEATING & AIR COND 29926 07/ 19/ 2018 RBT Nilson - ( 17) AC C& C 760-5616- 381018 680.00

Vendor 527000 - NILSON HEATING & AIR GOND. Total: 3, 920.00

Vendor: 956840 - NONNEMACHER, NAN

NONNEMACHER, NAN RBT7/ 2018 07/ 19/ 2018 RBT Nonnemacher - Central A 760-5616- 381012 275.00

Vendor 956840 - NONNEMACHER, NAN Total: 275. 00

Vendor: 530290 - NORTHERN TOOL & EQUIPMENT CO

NORTHERN TOOL & EQUIPME 40551208 07/ 19/ 2018 sandblast kit, nozzle 750-5553- 222001 99.12

Vendor 530290 - NORTHERN TOOL & EQUIPMENT CO Total: 99.12

Vendor: 531950- NOVASPECT INC

NOVASPECT INC CD99079912 07/ 19/ 2018 O- ri ngs for regs 710-141001 325. 59

Vendor 531950 - NOVASPECT INC Total: 325. 59

Vendor: 769958 - NOZCO INC

NOZCO INC 4025 07/ 19/ 2018 Service call to EDD Bldg. 710-5573-222005 105. 00

Vendor 769958 - NO2CO INC Total: 105. 00

Vendor: 540200 - OCCUPATIONAL MED CONSULTANTS

OCCUPATIONAL MED CONSU 21228 07/ 19/ 2018 June Drug Testing 710-5591- 331601 23.50

OCCUPATIONAL MED CONSU 21228 07/ 19/ 2018 June Drug Testing 730- 5591-331601 11. 75

OCCUPATIONAL M ED CONSU 21228 07/ 19/ 2018 June Drug Testing 750-5591- 331601 11. 75

Vendor 540200 - OCCUPATIONAL MED CONSULTANTS Total: 47.00

Vendor: 522500 - OMG MIDWEST INC

OMG MIDWEST INC 233971 07/ 19/ 2018 2 Ballasts - quartzite 710-5577- 530202 73.53

Vendor 522500 - OMG MIDWEST INC Total: 73.53

Vendor: 540322 - O' REILLY AUTO PARTS

O' REILLY AUTO PARTS 2345- 258895 07/ 19/ 2018 Contact cleaner 710- 141001 19. 98

O' REILLY AUTO PARTS 2345- 259885 07/ 19/ 2018 Contact cleaner 710- 141001 9. 99

Vendor 540322 - O' REILLY AUTO PARTS Total: 29.97

Vendor: 551250 - PAAPE COMPANIES INC.

PAAPE COMPANIES INC. 005893 07/ 19/ 2018 Reset HVAC controller 760-5593- 222005 142. 50

Vendor 551250 - PAAPE COMPANIES INC. Total: 142. 50

Vendor: 961204 - PALMER, GORDON

PALMER, GORDON RBT 7/ 2018 07/ 19/ 2018 RBT Palmer - Dishwasher 760-5616- 381501 25. 00

Vendor 961204 - PALMER, GORDON Total: 25. 00

Vendor: 561902- PITNEY BOWES BANK

PITNEY BOWES BANK INV0009804 07/ 19/ 2018 JULY 2018 POSTAGE 760-5591- 332100 1,446.00

Vendor 561902 - PITNEY BOWES BANK Total: 1, 446.00

Vendor: 562500 - PLUNKETTS INC

PLUNKETTS INC 5955266 07/ 19/ 2018 Weed control at MDC 760- 5623- 222005 397.45

PLUNKETTS INC 5978360 07/ 19/ 2018 General Pest Control 720-5573- 222005 6. 50

PLUNKETTS INC 5978360 07/ 19/ 2018 General Pest Control 740-5573- 222005 58.50

Vendor 562500 - PLUNKETTS INC Total: 462.45

Vendor: 565575 - POWER PRODUCTS & SERVICES, INC

POWER PRODUCTS & SERVICE 18169 07/ 19/ 2018 Steam flow meter for Firmeni 710- 5517- 530100 4,479.80

Vendor 565575 - POWER PRODUCTS & SERVICES, INC Total: 4,479.80

7/ 19/ 2018 12: 43'1- 47 ? M Page 10 of 17


Vendor Name Payable Number Post Date Description ( item) Account Number Amount

Vendor: 962964 - PREISINGER, ELLEN

PREISINGER, ELLEN RBT7/ 2018 07/ 19/ 2018 RBTPreisinger- Furnace 760-5616-381010 200.00

Vendor 962964 PREISINGER, ELLEN Total: 200.00

Vendor: 571500 - PUHLMANN LUMBER COMPANY

PUHLMANN LUMBER COMPA 394457 07/ 19/ 2018 2x4' s;4x8' s clairifier project 750-5553- 222010 73. 39

PUHLMANN LUMBER COMPA 394464 07/ 19/ 2018 Concrete forms 710-5573- 222305 24. 88

PUHLMANN LUMBER COMPA 394476 07/ 19/ 2018 Fasteners 760-5593- 222001 5. 44

PUHLMANN LUMBER COMPA 394590 07/ 19/ 2018 Steel door, door foam 710-5513- 222005 689. 16

PUHLMANN LUMBER COMPA 394614 07/ 19/ 2018 Pads for backhoe downriggers 730-5573- 222001 38.30

PUHLMANN LUMBER COMPA 394671 07/ 19/ 2018 wood shims, boards 710-5513- 222005 18.42

PUHLMANN LUMBER COMPA 394816 07/ 19/ 2018 al 710-5577-530202 16. 98

PUHLMANN LUMBER COMPA 394880 07/ 19/ 2018 2X10 boards 710-5577- 530202 31. 10

Vendor 571500 - PUHLMANN LUMBER COMPANY Total: 897. 67

Vendor: 000747 - PVS TECHNOLOGIES INC

PVS TECHNOLOGIES INC 240567 07/ 19/ 2018 ferric chloride 750-5551-221100 4, 260.79

Vendor 000747 - PVS TECHNOLOGIES INC Total: 4,260.79

Vendor: 000259 - PYAN, MICHAEL

PYAN, MICHAEL RBT 7/ 2018 07/ 19/ 2018 REIT Pyan - LED lighting 760-5616-381023 14. 00

Vendor D00259 - PYAN, MICHAEL Total: 14. 00

Vendor: 580350 - QUANTUM LABS INC

QUANTUM LABS INC 410253 07/ 19/ 2018 softskin nitrile gloves 750-5551- 221150 247.45

Vendor 580350 - QUANTUM LABS INC Total: 247.45

Vendor: 589755 - ROO EQUIP. CO/ POW ERPLAN

RDO EQUIP. CO/ POWERPLAN P74145 07/ 19/ 2018 check valve for Backhoe 720-5573- 222001 32. 12

RDO EQUIP. CO/ POWERPLAN P74145 07/ 19/ 2018 check valve for Backhoe 740-5573- 222001 289. 11

RDO EQUIP. CO/ POWERPLAN W12597 07/ 19/ 2018 Repair to brush chipper 710-5573- 222001 471.90

Vendor 589755 - RDO EQUIP. CO/ POWERPLAN Total: 793. 13

Vendor: 000109 - REINARTS, DENNIS

REINARTS, DENNIS RBT 7/ 2018 07/ 19/ 2018 RBT Reinarts - Room AC 760-5616- 381501 25. 00

Vendor 000109 - REINARTS, DENNIS Total: 25. 00

Vendor: 593650 - RESCO

RESCO 708443-00 07/ 19/ 2018 Large bushing covers 710- 141001 566.87

RESCO 716387-01 07/ 19/ 2018 Cross arm pins 710- 141001 298.82

RESCO 718133-00 07/ 19/ 2018 Photo controls for street lighti 710-141001 614.30

Vendor 593650 - RESCO Total: 1, 479.99

Vendor: 594250 - RETZLAFFS HARDWARE STORE

RETZLAFFS HARDWARE STOR 55398 07/ 19/ 2018 supplies 765- 5591- 220010 15.47

RETZLAFFS HARDWARE STOR 55406 07/ 19/ 2018 Calculator battery 710-5513- 222001 8. 98

RETZLAFFS HARDWARE STOR 55423 07/ 19/ 2018 bulb 710-5513- 222350 10. 99

RETZLAFFS HARDWARE STOR 55590 07/ 19/ 2018 Bulb 710-5513- 222005 8. 49

RETZLAFFS HARDWARE STOR 55600 07/ 19/ 2018 sealant silcone, great stuff G& 720-5573- 222140 13. 98

Vendor 594250 - RETZLAFFS HARDWARE STORE Total: 57.91

Vendor: 597728 - RIVER VALLEY LAWN CARE OF NEW ULM INC

RIVER VALLEY LAWN CARE OF 8112 07/ 19/ 2018 Lawn mowing at substations 710-5533- 222005 235.13

RIVER VALLEY LAWN CARE OF 8129 07/ 19/ 2018 Mowing substations 710-5533- 222005 128. 25

Vendor 597728 - RIVER VALLEY LAWN CARE OF NEW ULM INC Total: 363.38

Vendor: 597750 - RIVER VIEW SANITATION/ RVS ShreddingRIVER VIEW SANITATION/ RVS 9631 07/ 19/ 2018 Dumpster pickup 710-5573- 349060 130.43

RIVER VIEW SANITATION/ RVS 9632 07/ 19/ 2018 MDC Dumpster pickup 760-5623- 222005 107.57

RIVER VIEW SANITATION/ RVS 9633 07/ 19/ 2018 20th dumpster pickup 750-5553- 349060 67.57

RIVER VIEW SANITATION/ RVS 9634 07/ 19/ 2018 July 2018 Dumpster 730-5573- 349060 67.57

RIVER VIEW SANITATION/ RVS 9635 07/ 19/ 2018 plant dumpster fee; grease di 750-5553- 222010 2, 679.30

RIVER VIEW SANITATION/ RVS 9635 07/ 19/ 2018 plant dumpsterfee; grease di 750-5553-349060 134.37

RIVER VIEW SANITATION/ RVS 9636 07/ 19/ 2018 Garbage Pickup 720-5573- 349060 6. 76

RIVER VIEW SANITATION/ RVS 9636 07/ 19/ 2018 Garbage Pickup 740-5513-349060 60.81

RIVER VIEW SANITATION/ RVS 9637 07/ 19/ 2018 Dumpster pickup 710-5573- 349060 222.70

Vendor 597750 - RIVER VIEW SANITATION/ RVS Shredding Total: 3,477.08

7/ 19/ 20t8 12: 43: 47 PM pr, g:: 11 of 17



Vendor: 000807 - ROERISH, BRIAN & CARRI

ROERISH, BRIAN & CARRI RBT 7/ 2018 07/ 19/ 2018 RBT Roerish - Central AC 760-5616-381012 275.00

Vendor 000807 - ROERISH, BRIAN & CARRI Total: 275.00

Vendor: 601150 - ROMAN, NICK

ROMAN, NICK RBT 7/ 2018 07/ 19/ 2018 RBT Roman - Central AC 760-5616-381012 275. 00

Vendor 601150 - ROMAN, NICK Total: 275.00

Vendor: 602750 - RUNNINGS

RUNNINGS 5693236 07/ 19/ 2018 Rope Clip, zinc plate 740-5573- 222145 15. 80

RUNNINGS 5693238 07/ 19/ 2018 Service Shop Parts 740-5573-222001 3. 48

RUNNINGS 5699261 07/ 19/ 2018 Drain tile 710-5573- 222305 14. 75

RUNNINGS 5702035 07/ 19/ 2018 Paint for shop bathroom 730-5573- 222005 42.35

RUNNINGS 5702316 07/ 19/ 2018 Quick elbows & recip saw bla 730-5573-222140 31.97

RUNNINGS 5702391 07/ 19/ 2018 Returned quick elbow 730-5573- 222140 9. 99

RUNNINGS 5702730 07/ 19/ 2018 hose clamps 720- 5573-222140 7. 96

RUNNINGS 5702736 07/ 19/ 2018 Silicone sealant 730-5573- 222005 3. 49

RUNNINGS 5703595 07/ 19/ 2018 Repairs on cut-quik & chop sa 730-5573-222001 288.77

RUNNINGS 5703680 07/ 19/ 2018 Quickcut saw 710-5573- 222001 949.95

RUNNINGS 5704047 07/ 19/ 2018 Parts cabinet, lock pins, dryw 730- 5573-222001 56. 94

RUNNINGS 5704088 07/ 19/ 2018 Ret parts cabinet -$13. 99 & b 730-5573-222001 7. 00

RUNNINGS 5704701 07/ 19/ 2018 Bleach 710- 5513-226010 10. 97

RUNNINGS 5707737 07/ 19/ 2018 Hex conct screw, tapcon bit 740- 5573-222005 11. 68

RUNNINGS 5707996 07/ 19/ 2018 gas weed trimmer 750-5553- 222008 159. 95

RUNNINGS 5708441 07/ 19/ 2018 nippole galv., valve boiler drai 720-5573- 222005 3. 23

RUNNINGS 5708441 07/ 19/ 2018 nippole galv., valve boiler drai 740- 5573- 222005 29. 03

RUNNINGS 5708753 07/ 19/ 2018 Cutting blade arbor reducers 710-141001 20. 19

RUNNINGS 5709197 07/ 19/ 2018 wood shims, bin products 710-5513- 222005 4. 69

RUNNINGS 5709897 07/ 19/ 2018 Dewalt sledge hammer 710-5573- 222001 48.99

RUNNINGS 5709931 07/ 19/ 2018 Hose Recoil Air 740-5573- 222005 17. 49

RUNNINGS 5710217 07/ 19/ 2018 Charge & sync Cable 3' Apple 740-5571- 222025 9. 99

RUNNINGS 5710259 07/ 19/ 2018 Utility lashing strap 710-5573- 222001 4.59

RUNNINGS 5712037 07/ 19/ 2018 Gooseneck Connector single 740-5573- 222145 9. 98

RUNNINGS 5712633 07/ 19/ 2018 bore bruch 710-5513- 222351 6. 38

RUNNINGS 5713884 07/ 19/ 2018 Cut off saw repairs 730-5573- 222001 82.09

RUNNINGS 5716208 07/ 19/ 2018 Repairtamper 710-5573- 222001 107.20

RUNNINGS 5716398 07/ 19/ 2018 coffee maker 750-5551- 226010 44.99

RUNNINGS 5716419 07/ 19/ 2018 rubber plug 710-5513- 222350 3. 99

RUNNINGS 5716863 07/ 19/ 2018 Tile markers for leak detector 730-5573- 222001 7. 98

RUNNINGS 5717987 07/ 19/ 2018 Aligning Bare 30"/ Wrecking B 720-5573- 222001 2. 70

RUNNINGS 5717987 07/ 19/ 2018 Aligning Bare 30"/ Wrecking B 740-5573- 222001 24. 28

RUNNINGS 5718009 07/ 19/ 2018 Hammer ballpein, screw pin 720-5573- 222001 5. 60

RUNNINGS 5718009 07/ 19/ 2018 Hammer ballpein, screw pin 740-5573-222001 50.38

Vendor 602750 - RUNNINGS Total: 2, 064.84

Vendor: 616000 - SBS CYBERSECURITY LLC

SBS CYBERSECURITY LLC 18- 2549 07/ 19/ 2018 KnowBe4 License agrmt July- 765- 5591- 347113 585. 00

Vendor 616000 - SBS CYBERSECURITY LLC Total: 585.00

Vendor: 619700 - SCHILLING SUPPLY COMPANY

SCHILLING SUPPLY COMPANY 665279-00 07/ 19/ 2018 Cups, towels, wiper scrims 710-141001 188. 50

SCHILLING SUPPLY COMPANY 667784-00 07/ 19/ 2018 Paper towels, wiper scrim po 710- 141001 164. 88

Vendor 619700 - SCHILLING SUPPLY COMPANY Total: 353. 38

Vendor: 619800 - SCHIMBERG COMPANY

SCHIMBERG COMPANY 2184979-00 07/ 19/ 2018 pressure gauges 710-5513-222350 665. 85

Vendor 619800 SCHIMBERG COMPANY Total: 665.85

Vendor: 622910 - SCHMITZ, THOMAS E

SCHMITZ, THOMAS E RBT 7/ 2018 07/ 19/ 2018 RBT Schmitz - ( 6) Releaf Trees 760-5616-381201 227. 88

Vendor 622910 - SCHMITZ, THOMAS E Total: 227. 88

Vendor: 635115 - SEARS COMMERCIAL ONE

SEARS COMMERCIAL ONE T111341 07/ 19/ 2018 Shop vac filters 760- 5623- 222001 17. 99

SEARS COMMERCIAL ONE T224324 07/ 19/ 2018 Refrigerator, microwave for 760-5623- 222005 629.98

7119/ 2018 12: 43: 47 PM Paye 12 of 17


Vendor Name Payable Number Post Date Description ( item) Account Number Amount

SEARS COMMERCIAL ONE T401346 07/ 19/ 2018 Cordless flashlight bulbs 760-5623- 222001 9. 98

Vendor 635115 - SEARS COMMERCIAL ONE Total: 657. 95

Vendor: 610530 - SEH

SEH 352970 07/ 19/ 2018 Heinenhill Ground Storage Ta 740-5517- 530325 3, 548. 55

SEH 353085 07/ 19/ 2018 On-site Chlorine Generation 740-5517- 520020 6, 494. 37

SEH 353395 07/ 19/ 2018 Update for New Ulm Airport T 740- 5517- 530325 4,456.93

Vendor 610530 - SEH Total: 14, 499.85

Vendor: 000766 - SHI INTERNATIONAL CORP

SHI INTERNATIONAL CORP 808476416 -water 07/ 19/ 2018 web camera 720-5591- 332100 5. 50

SHI INTERNATIONAL CORP 808476416 -water 07/ 19/ 2018 web camera 740-SS91- 332100 49.50

Vendor 000766 - SHI INTERNATIONAL CORP Total: 55. 00

Vendor: R00701- SIEGFRIED, HELEN

SIEGFRIED, HELEN RBT 7/ 2018 07/ 19/ 2018 RBT Siegfried - Clothes dryer 760-5616-381501 50.00

Vendor R00701- SIEGFRIED, HELEN Total: 50. 00

Vendor: 650850 - SIMONEAU STERLING MIDWEST CORP

SIMONEAU STERLING MIDWE 12245 07/ 19/ 2018 Burner control issue 710-5513- 222350 611.25

SIMONEAU STERLING MIDWE 12275 07/ 19/ 2018 Timer reprogramming 710-5513- 222350 427.88

Vendor 650850 - SIMONEAU STERLING MIDWEST CORP Total: 1,039.13

Vendor: R01259 - STADICK, LES

STADICK, LES RBT- 07/ 2018 07/ 19/ 2018 RBT STADICK - DISHWASHER 760-5616-381501 25. 00

Vendor R01259 - STADICK, LES Total: 25.00

Vendor: 680700 - STATE SUPPLY COMPANY

STATE SUPPLY COMPANY 539089 07/ 19/ 2018 Cage unit 710-5513- 222350 181. 14

Vendor 680700 - STATE SUPPLY COMPANY Total: 181. 14

Vendor: 000562 - STEP SAVER INC

STEP SAVER INC 119464 07/ 19/ 2018 Bulk salt, iron out 710-5513- 222350 314. 75

STEP SAVER INC 119700 07/ 19/ 2018 bulk salt, iron out 710-5513- 222350 257. 90

Vendor 000562 - STEP SAVER INC Total: 572.65

Vendor: R01260 - THOM, RICK

THOM, RICK RBT- 07/ 2018 07/ 19/ 2018 RBT THOM - DISHWASHER, RE 760-5616-381501 75. 00

Vendor R01260 - THOM, RICK Total: 75. 00

Vendor: 718525 - TMH PLUMBING and HEATING LLC

TMH PLUMBING and HEATIN 1501 07/ 19/ 2018 1200 North Jefferson -service 1 740-5573- 222145 746. 00

Vendor 718525 - TMH PLUMBING and HEATING LLC Total: 746.00

Vendor: 000647 - TOM ROIGER

TOM ROIGER 4062 07/ 19/ 2018 710 JD backhoe 720-5573- 222001 36. 25

TOM ROIGER 4062 07/ 19/ 2018 710 JD backhoe 740-5573- 222001 326.25

Vendor 000647 - TOM ROIGER Total: 362.50

Vendor: R01261- TORGUSEN, DIANE

TORGUSEN, DIANE RBT- 07/ 2018 07/ 19/ 2018 RBT TORGUSEN - REFRIG & D 760-5616-381501 50.00

Vendor R01261 - TORGUSEN, DIANE Total: 50.00

Vendor: 722400 - TRENCHERS PLUS INC

TRENCHERS PLUS INC RT40620 07/ 19/ 2018 Trencher repair 710-5573- 222001 2, 096.64

Vendor 722400 - TRENCHERS PLUS INC Total: 2,096.64

Vendor: 724525 - TURBO SERVICES INC

TURBO SERVICES INC V18037 07/ 19/ 2018 Used replacement SPC for #7 710-5513- 222357 3, 850.00

Vendor 724525 - TURBO SERVICES INC Total: 3,850.00

Vendor: 341906 - TYLER TECHNOLOGIES

TYLER TECHNOLOGIES 025- 228671 07/ 19/ 2018 Insite transaction fees - U8 760-5591- 347118 2, 626.25

Vendor 341906 - TYLER TECHNOLOGIES Total: 2, 626.25

Vendor: 736550 - UNITED PARCEL SERVICE

UNITED PARCEL SERVICE 236W2E248 07/ 19/ 2018 Shipping - Power Plant 710-5513- 222357 19.47

UNITED PARCEL SERVICE 236W2E248 07/ 19/ 2018 Shipping - EDD 710-5573- 222001 20. 61

UNITED PARCEL SERVICE 236W2E248 07/ 19/ 2018 Shipping - Gas 730-5573- 222001 12. 99

UNITED PARCEL SERVICE 236W2E258 07/ 19/ 2018 Return costs 710-5513-222357 7. 42

7/ 19/ 20-18 12: 4': 47 I' M Page 13 of i7



UNITED PARCEL SERVICE 236W2E268 07/ 19/ 2018 Sent whistle valve back for Po 710-5513- 222350 9. 59

UNITED PARCEL SERVICE 236W2E268 07/ 19/ 2018 Package for Power Plant 710-5513-222357 48.88

UNITED PARCEL SERVICE 236W2E268 07/ 19/ 2018 Sent welding lens in for repair 730-5573- 222001 13. 23

UNITED PARCEL SERVICE 236W2E288 07/ 19/ 2018 Shipping fees 710-5513- 222350 73. 41

Vendor 736550 - UNITED PARCEL SERVICE Total: 205. 60

Vendor: 738820 - USA BLUE BOOK

USA BLUE BOOK 609150 07/ 19/ 2018 prybar set, nozzles, bush, nippl 750-5553- 222001 301.47

Vendor 738820 - USA BLUE BOOK Total: 301. 47

Vendor: 748790 - VIKING ELECTRIC SUPPLY INC

VIKING ELECTRIC SUPPLY INC 5001528337.003 07/ 19/ 2018 2" pipe straps 710-141001 51.80

VIKING ELECTRIC SUPPLY INC 5001587961.001 07/ 19/ 2018 Expansion couplings 710-141001 304.71

VIKING ELECTRIC SUPPLY INC 5001600835.001 07/ 19/ 2018 PVC cement, #8 wire 710- 141001 272.48

VIKING ELECTRIC SUPPLY INC 5001601892. 001 07/ 19/ 2018 Meter sockets 710- 141001 313. 68

VIKING ELECTRIC SUPPLY INC 5001636222. 001 07/ 19/ 2018 12- 2 wire 710- 141001 744.28

VIKING ELECTRIC SUPPLY INC 5001686058.001 07/ 19/ 2018 PVC fittings 710- 141001 126.99

Vendor 748790 - VIKING ELECTRIC SUPPLY INC Total: 1, 813.94

Vendor: R00599 - WEBER, ED

WEBER, ED RBT 7/ 2018 07/ 19/ 2018 RBT Weber- LED lighting 760-5616- 381023 12. 99

Vendor R00S99 - WEBER, ED Total: 12.99

Vendor: R01262 - WEIGEL, JASON

WEIGEL, JASON RBT-07/ 2018 07/ 19/ 2018 RBTWEIGEL- FURNACE 760-5616- 381010 200.00

Vendor R01262 - WEIGEL, JASON Total: 200.00

Vendor: R00812 - WENDLAND, DAVID or LEAH

WENDLAND, DAVID or LEAH RBT 7/ 2018 07/ 19/ 2018 RBT Wendland - Central AC 760- 5616- 381012 350.00

Vendor R00812 - WENDLAND, DAVID or LEAH Total: 350. 00

Vendor: 000498 - WENISCH, JILL

WENISCH, JILL RBT 7/ 2018 07/ 19/ 2018 RBT Wenisch - Room AC 760-5616-381501 25. 00

Vendor 000498 - WENISCH, JILL Total: 25.00

Vendor: 763510 - WESCO DISTRIBUTION INC

WESCO DISTRIBUTION INC 228821 07/ 19/ 2018 3504/ 0 wire 710-141001 2, 212. 31

WESCO DISTRIBUTION INC 232677 07/ 19/ 2018 8' crossarms 710-141001 445. 67

WESCO DISTRIBUTION INC 232678 07/ 19/ 2018 J hooks 710- 141001 49.70

WESCO DISTRIBUTION INC 236840 07/ 19/ 2018 Cold shrink 710-141001 1, 387. 67

WESCO DISTRIBUTION INC 236841 07/ 19/ 2018 5/ 8" x 10' ground rods 710-141001 575. 05

WESCO DISTRIBUTION INC 243857 07/ 19/ 2018 Cable cleaning pads 710- 141001 299.25

Vendor 763510- WESCO DISTRIBUTION INCTotal: 4,969.65

Vendor: 765340- WESTRUM LEAK DETECTION, INC.

WESTRUM LEAK DETECTION, 1 4246 07/ 19/ 2018 Computerized Leak Deection 740-5571-331450 3, 800.00

Vendor 765340 - WESTRUM LEAK DETECTION, INC. Total: 3, 800.00

Vendor: 790550 - ZEE MEDICAL SERVICE

ZEE MEDICAL SERVICE 54059741 07/ 19/ 2018 Restock medical supplies - Po 710-5511-221150 129. 20

ZEE MEDICAL SERVICE 54059741 07/ 19/ 2018 Restock medical supplies - ED 710-5571- 221150 99.95

ZEE MEDICAL SERVICE 54059741 07/ 19/ 2018 Restock medical supplies - Ga 730-5571-221150 53. 75

ZEE MEDICAL SERVICE 54059741 07/ 19/ 2018 Restock medical supplies - Ad 760-5591-221150 51.60

Vendor 790550 - ZEE MEDICAL SERVICE Total: 334. 50

Vendor: 791001- ZEP SALES & SERVICE

ZEP SALES & SERVICE 9003497227 07/ 19/ 2018 Zep meter mist, Zep 40, Zep- 710-141001 320. 26

Vendor 791001- ZEP SALES & SERVICE Total: 320.26

Vendor: 791265 - ZINNIEL UTILITY CONTRACTING, INC

ZINNIEL UTILITY CONTRACTIN 18- 051 07/ 19/ 2018 Directional Drill WO# 36904 740-5573- 222145 1, 500.00

Vendor 791265 - ZINNIEL UTILITY CONTRACTING, INC Total: 1, 500.00

Grand Total: 366,734.72

7/ 19/ 21). tP 12 44- 47 PM Page 14 of 17


Fund SummaryFund

710 - ELECTRIC FUND

720 - DISTRICT ENERGY

730 - NATURAL GAS FUND

740 - WATER FUND

750- WASTEWATER FUND

760 - ADMINISTRATIVE FUND

765 - INFORMATION TECHNOLOGY SV

Account Number

710- 141001

710-5511- 221150

710-5511- 221200

710-5511- 221205

710-5511-221208

710-5513- 222001

710- 5513- 222005

710- 5513- 222350

710- 5513- 222351

710- 5513- 222357

710-5513- 226010

710- 5517- 530100

710-5533- 222005

710- 5571- 221150

710-5571- 222025

710-5573- 222001

710-5573- 222005

710-5573- 222305

710-5573- 222320

710-5573- 349060

710-5577-530202

710-5577- 530204

710-5591-220010

710-5591- 225310

710-5591- 331601

710-5591-332100

710-5591- 333050

710-5591-347040

720-5571- 222025

720-5573- 222001

720-SS73- 222005

720-5573- 222140

720-5573- 222145

720-5573- 349060

720-5577-530322

720-5591- 220010

720-5591-332100

720-5593- 224001

730-5571- 221150

730-5571- 222025

730-5571- 226010

730-5573- 222001

730- 5573- 222005

730- 5573- 222140

730-5573-349060

730-5577- 550020

Grand Total:

Account SummaryAccount Name

Inventory materials & su

Safety equipment

Station expenses coolingStation expenses boiler

Water treatment

Tools & equipment

Maintenance buildings

Boiler plant

Electric plant

Gas turbine

Supplies

Boiler plant improveme


Safety equipmentMaintenance vehicles

Tools & equipment


Lines underground

Station equipment

Garbage disposal

Conductors & devices -

Overhead & undergroun

Office supplies

Cost of sales city

Drug testing program

Communications

Travel conferences & sc

Subscriptions & member

Maintenance vehicles

Tools & equipment


Mains & accessories

Service line repair

Garbage disposal

Mains high pressure

Office supplies

Communications

Office furniture & equip

Safety equipmentMaintenance vehicles

Supplies

Tools & equipment


Mains & accessories

Garbage disposal

Tools & equipment

Expense Amount

191, 669.42

19, 576.99

14, 767.40

75, 093. 17

14, 728.73

49, 162. 87

1, 736. 14

366,734.72

Expense Amount

141, 556. 17

129. 20

199.92

110.33

372.95

131.75

1, 056.92

2, 579.67

7, 672. 63

5, 764.44

10.97

4,479. 80

363. 38

261.06

691. 74

4, 890. 11

138. 15

610.83

63. 59

353. 13

16, 325. 25

649.53

63. 48

84.04

123. 54

788. 34

1,816. 00

382. 50

25. 02

88. 03

46.49

121. 90

314.72

6. 76

18, 940.00

8. 03

15. 70

10. 34

53. 75

110.01

55. 26

918.81

334.75

694.92

67.57

9, 574.50

Post Dates: - 07/ 19/ 2018

Report Summary

7( 19/ 2018 _12: 43, 47 PM Page 15 of 17


Account SummaryAccount Number Account Name Expense Amount

730-5591- 331601 Drug testing program 61.77

730-5591- 332100 Communications 316.06

730-5591- 349115 Safety allowance 2, 580.00

740- 141030 Inventory chemicals 15, 167.93

740-5511- 226010 Supplies 730.37

740-5511- 331325 Outside lab tests 271.00

740-5513- 222230 Wells equipment 2, 841.45

740-5513- 222233 Well houses 200.00

740-5513- 222235 Water filter treatment p 9. 99

740-5513- 349060 Garbage disposal 60.81

740-5517- 520020 Treatment plant improv 6,494. 37

740-5517- 530325 Wells & reservoirs 8,005.48

740-5571- 222025 Maintenance vehicles 235. 21

740-5571-331400 Locating 1,400.00

740-5571-331450 Leak detection 3,800.00

740-5573- 222001 Tools & equipment 1, 175. 05

740-5573- 222005 Maintenance buildings 447.55

740-5573- 222135 Meters & regulators 296.92

740-5573- 222140 Mains & accessories 10,495.37

740-5573- 222145 Service line repair 20,671.34

740- 5573- 222205 Elevated tower airport 150.00

740- 5573- 222222 Reservoirs 3M gallon 200.00

740- 5573- 222225 Reservoirs 4.5M gallon 340.00

740-5573- 222240 Northside booster statio 100.00

740-5573- 222242 Cottonwood Booster Sta 180.00

740- 5591- 220010 Office supplies 72.23

740- 5591- 332100 Communications 1, 655. 08

740- 5593- 224001 Office furniture & equip 93.02

750-5551- 221050 Vehicle & Equip Unl Gas 113. 65

750-5551- 221100 Chemical & supplies 6, 543. 17

750- 5551- 221110 Laboratory supplies & ex 299.53

750- 5551- 221150 Safety equipment 266. 46

750- 5551- 226010 Supplies 97. 33

750- 5551- 331325 Outside lab tests 243. 00

750-5553- 222001 Tools & equipment 560.42

750-5553- 222008 Maintenance grounds 258.95

750-5553- 222010 Maintenance plant 5, 122. 92

750-5553- 349060 Garbage disposal 201. 94

750- 5573- 222455 Sewer lifts 259. 90

750-5591- 220010 Office supplies 589. 86

750- 5591- 331601 Drug testing program 61.77

750- 5591- 332100 Communications 109. 83

760- 5581- 332100 Communications 23. 53

760- 5583- 222001 Tools & equipment 79.98

760- 5591- 113300 Wellness program 127. 50

760- 5591- 220010 Office supplies 68.68

760- 5591- 221150 Safety equipment 51.60

760- 5591- 330040 Legalfees 3, 014.71

760- 5591- 332100 Communications 1, 500.91

760- 5591- 333050 Travel conferences & sc 35.00

760- 5591- 347118 Credit card and online bi 2, 626.25

760- 5591- 349115 Safety allowance 5, 375. 00

760- 5593- 222001 Tools & equipment 5. 44

760- 5593- 222005 Maintenance buildings 301.47

760- 5597- 550010 Office furniture & equip 2, 374.50

760- 5601- 332100 Communications 700.00

760- 5616- 347040 Subscriptions & member 382. 50

760- 5616- 381010 Furnace rebate 1,400.00

Post Dates: - 07/ 19/ 2018

I ' 12_018 12: 43: 47 I' M Page 16 of 17


Account SummaryAccount Number Account Name Expense Amount

760-5616- 381012 Air conditioning rebate 5, 640.00

760-5616- 381015 Programable thermostat 96.00

760- 5616- 381018 Air conditioning cleaning 4, 536.00

760-5616- 381022 High efficiency light reba 7, 324. 70

760-5616- 381023 Residential lighting reba 77. 96

760-5616- 381040 Water heater rebate 75. 00

760-5616- 381201 Shade tree program 227. 88

760-5616- 381501 Energy Star rebates 435.00

760-5616- 388901 Miscellaneous educatio 70.00

760- 5616- 388905 Low Income Programs 500.00

760-5621-220010 Office supplies 199. 38

760-5621- 221010 Misc small parts 175. 92

760-5623- 222001 Tools & equipment 27.97

760-5623- 222005 Maintenance buildings 1, 189.99

760-5641- 347040 Subscriptions & member 10,430.58

760-5641- 350010 Miscellaneous 89.42

765- 5591- 220010 Office supplies 15.47

765- 5591- 224100 Computer supplies & eq 54.03

765- 5591-332100 Communications 134.85

765- 5591- 347113 Licenses & fees 1,451.40

765- 5593- 222001 Tools & equipment 80.39


Project Account Summary

Project Account Key Expense Amount

None** 366, 734.72


Post Dates: - 07/ 19/ 2018

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