ELK RIVER MUNICIPAL UTILITIES96bda424cfcc34d9dd1a-0a7f10f87519dba22d2dbc6233a731e5.r41.cf2.rackcdn.…SPECIAL MEETING OF THE UTILITIES COMMISSION March 17, 2015, 3:30 P.M. Utilities

SPECIAL MEETING OF THE

UTILITIES COMMISSION

March 17, 2015, 3:30 P.M.

Utilities Conference Room

Mission Statement: To provide our customers with safe, reliable, cost effective and quality long

term electric and water utility service. To communicate and educate our customers in the use of

utility services, programs, policies, and future plans. These products and services will be

provided in an environmentally and financially responsible manner.

13069 Orono Parkway, P.O. Box 430

Elk River, MN 55330-0430

763.441.2020

www.elkriverutilities.com

AGENDA

1.0 CALL MEETING TO ORDER

1.1 Pledge of Allegiance

1.2 Commissioner Oath of Office, Election of 2014 Officers, and 2014 Committee Appointments

1.3 Consider the Agenda

1.4 Recognition of Volunteerism

2.0 CONSENT AGENDA (Routine or noncontroversial items. Approved by one motion.)

2.1 Check Register

2.2 Previous Meeting Minutes

2.3 Financial Statements

3.0 OPEN FORUM (Non agenda items for discussion. No action taken during this meeting.)

4.0 OLD BUSINESS

4.1 2014 Electric Reliability Report

5.0 NEW BUSINESS

5.1 National Information Solutions Cooperative Software Implementation Update - Verbal

5.2 Electric Cable Bids

5.3 Otsego Substation Upgrade

5.4 Well #2 Project Update and Presentation

5.5 2015 American Public Power Association Legislative Rally – Verbal

6.0 OTHER BUSINESS

6.1 Staff Updates

6.2 Set Date for Next Meeting

6.3 Closing of Meeting: “Meeting to be Closed pursuant to MN Statute

13D.05, Subd. 3(c)(3) to develop or consider offers or counteroffers for

the purchase or sale of real or personal property.”

a Call Closed Session to Order

b Discussion

c Adjourn Closed Session

6.4 Adjourn Regular Meeting

http://www.elkriverutilities.com/

STATE OF MINNESOTA

COUNTY OF SHERBURNE

CITY OF ELK RIVER

OATH OF OFFICE

I, Daryl Thompson, do solemnly swear that I will support the Constitution of the United States and the Constitution of the State of Minnesota, and will discharge faithfully the duties of Utilities Commissioner in the City of Elk River, Minnesota, according to law and to the best of my judgment and ability. ___________________________________ Daryl Thompson Subscribed and sworn to before me this 17th day of March, 2015. _________________________________ Commission Chair or Notary Public

1

Payroll/LaborCheck Register Totals

Page: 103/10/2015 3:13:47 pm

Elk River Municipal Utilities

Pay Date: 02/13/2015 To 02/13/2015

Revision: 67929

Pays Job Amount Hours96,430.17 2,823.502 Reg Hrly1,157.77 29.753 Overtime1,747.99 48.085 On-Call/Stand-by

28.88 0.0024 FLSA325.20 8.0010 Bonus Pay450.00 0.0018 Commissioner Reimb.50.00 0.00104 Commission Stipend

8,537.66 237.25VAC Vacation Pay960.23 26.50SICK Sick Pay

0.00 0.00HOL Holiday Pay0.00 0.00HALF Half Vacation Pay0.00 0.001/2S Half Sick Pay

294.18 5.505-2 On-Call/Stand-by/OT9.76 0.0011 Bonus $

Pay Total: 109,991.84 3,178.58

/pro/rpttemplate/acct/2.30.1/pl/PL_CHK_REG_TOTALS.xml.rpt KSANDSTRO252032

Job Amount

2 87,498.37

3 158.36

4 970.38

5 1,609.03

24 0.00

10 284.55

VAC 5,559.91

SICK 2,482.37

HOL 10,679.72

HALF 0.00

1/2S 0.00

5-2 0.00

11 8.54

109,251.23Pay Total: 3,168.33

25203 /pro/rpttemplate/acct/2.30.1/pl/PL_CHK_REG_TOTALS.xml.rpt KSANDSTRO

Half Sick Pay 0.00

On-Call/Stand-by/OT 0.00

Bonus $ 0.00

Sick Pay 74.75

Holiday Pay 312.00

Half Vacation Pay 0.00

FLSA 0.00

Bonus Pay 7.00

Vacation Pay 145.50

Overtime 3.50

Double Time 12.50

On-Call/Stand-by 48.08

Check Register Totals

Pay Date: 02/27/2015 To 02/27/2015Pays Hours

Reg Hrly 2,565.00


Revision: 67929

03/10/2015 3:24:27 PM Payroll/Labor Page: 1

3

CHECK REGISTER

February, 2015

APPROVED BY:

JOHN J. DIETZ

DARYL THOMPSON

ALLAN E. NADEAU

4

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Accounts PayableCheck Register


02/01/2015 To 02/28/2015Bank Account: 1 - ELECTRIC/GENERAL FUND

Check /Tran Date

PmtType AmountVendor NameVendor Reference

WIRE878 02/02/2015 9999 PTL SERVICES PLT SERVICES TRAINING CLASS 160.00

WIRE879 02/02/2015 9999 KENTUCKY FRIED CHICKEN LUNCH FOR NISC TRAINING 55.55LUNCH FOR NISC TRAINING 13.89

Total for Check/Tran - 879: 69.44

WIRE880 02/02/2015 9999 AMAZON CORK BOARD, MAP PINS 209.18

WIRE881 02/03/2015 9999 CUB FOODS POP & CHIPS FOR NISC TRAINING 19.33POP & CHIPS FOR NISC TRAINING 4.83


WIRE882 02/03/2015 9999 PAPA JOHNS LUNCH FOR NISC TRAINING 76.34LUNCH FOR NISC TRAINING 19.08


WIRE883 02/04/2015 9999 JIMMY JOHNS LUNCH FOR NISC TRAINING 87.08LUNCH FOR NISC TRAINING 21.77


WIRE884 02/05/2015 9999 PTL SERVICES PTL SERVICES M. PRICE 160.00

WIRE885 02/05/2015 9999 DICKEY'S BBQ PIT LUNCH FOR NISC TRAINING 104.80LUNCH FOR NISC TRAINING 26.20


WIRE886 02/06/2015 9999 LEEANN CHIN LUNCH FOR NISC TRAINING 113.44LUNCH FOR NISC TRAINING 28.36


WIRE887 02/09/2015 9999 DOLLAR TREE STORE BAGS FOR RSVP VOLUNTEERS-SPECIAL M 14.96

WIRE888 02/09/2015 9999 COMFORT INN HOTEL FOR J. MURRAY-UMMA WINTER M 247.16

CHK68008 02/03/2015 6106 AID ELECTRIC CORPORATION Supplies 185.42Supplies 46.35


CHK68009 02/03/2015 150 ALARM PRODUCTS DIST, INC Security inv parts 223.06Voice Module 76.87

/pro/rpttemplate/acct/2.30.1/ap/AP_CHK_REGISTER.xml.rpt252035

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CHK68010 02/03/2015 4531 AT & T MOBILITY Cellphones and iPads 835.82Cellphones and iPads 208.95

Total for Check/Tran - 68010: 1,044.77

CHK68011 02/03/2015 2920 BATTERIES PLUS BULBS Batteries 72.06

CHK68012 02/03/2015 75 DEANO'S COLLISION & MECHANICAL SP Repairs Unit #32 4,105.55

CHK68013 02/03/2015 8840 ELITE MEDIA DESIGN OF ELK RIVER Monthly hosting of website 59.60Monthly hosting of website 59.60Monthly hosting of website 29.80


CHK68014 02/03/2015 671 FASTENAL COMPANY Zinc square nut 22.44Supplies 39.54


CHK68015 02/03/2015 28 G & K SERVICES SERVICES Mats & towels 84.27Mats & towels 21.07


CHK68016 02/03/2015 8494 MITCH GIRTZ Expenses 01-15 45.28

CHK68017 02/03/2015 809 HAWKINS, INC. Water Chemicals 890.82

CHK68018 02/03/2015 6836 INNOVATIVE OFFICE SOLUTIONS, LLC Office supplies 308.02Office supplies 77.01Return wall calendar -22.63Return wall calendar -5.66


CHK68019 02/03/2015 3419 MCDOWALL COMPANY Roof management agreement for 2015 1,020.00Roof management agreement for 2015 255.00


CHK68020 02/03/2015 476 MINNESOTA AWWA Water operator school - Volk 175.00

CHK68021 02/03/2015 16 MINNESOTA DEPT OF HEALTH Water Supply Syst Operator Class A - Vol 32.00


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CHK68022 02/03/2015 3256 MINNESOTA DNR ECO-WATERS 2014 MN DNR-ANNUAL REPORT OF WATE 11,592.89

CHK68023 02/03/2015 39 MMUA Training - R Stuhr, T Hubbard, J Murray 995.002015 Winter Legislatvie Conference Tom S 250.00


CHK68024 02/03/2015 3769 O'REILLY AUTOMOTIVE STORES, INC Wiper blades Truck #24 17.08

CHK68025 02/03/2015 572 RAMADA MARSHALL Hotel room for Matt Schwartz 105.16Hotel room for Tony Ross 105.16Hotel room for Zac Johnson 105.16Hotel room for Mitch Girtz 105.16Hotel room for Aaron White 105.16


CHK68026 02/03/2015 7798 MATT SCHWARTZ Expenses 01-15 38.08

CHK68027 02/03/2015 227 SHOE MENDERS & SADDLERY Boots 195.00

CHK68028 02/03/2015 55 WESCO RECEIVABLES CORP. Fiberglass Cleaner 120.77

CHK68029 02/13/2015 685 ADI Slim Line W/Sensor 196.00Security inventory parts 2,811.565800 PIR Wireless Motion 508.53Security GSM rebate -125.00


CHK68030 02/13/2015 7308 ADVANTAGE BILLING CONCEPTS BILLING SECURITY MED ALERTS 100.00

CHK68031 02/13/2015 150 ALARM PRODUCTS DIST, INC Security supplies 294.17Prox Tag Arming 120.56Security parts 145.47Pendant DXSLRC 301.88Concord Voice Mod 133.59


CHK68032 02/13/2015 1 AMERICAN PUBLIC POWER ASSOC DEED program invoice 2,113.402015 APPA legislative rally 244.00


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2015 APPA legislative rally 61.00


CHK68033 02/13/2015 2920 BATTERIES PLUS BULBS Battery for Sizzo lift 384.41Batteries 7.98Batteries 293.91


CHK68034 02/13/2015 6138 BLUE EGG BAKERY January 2015 43.20January 2015 10.80


CHK68035 02/13/2015 11 CITY OF ELK RIVER FF from City's metered accts taken twice 1,630.002014 Shared services 50,317.362014 Shared services 5,106.212014 Shared services 6,156.882014 Shared services 1,644.102014 Shared services 396.482014 Shared services 4,998.502014 Shared services 12,579.352014 Shared services 1,276.562014 Shared services 1,539.222014 Shared services 411.022014 Shared services 99.122014 Shared services 1,249.63Parts and labor for Unit 19 814.12December fuel usage 2,392.34December fuel usage 547.60December fuel usage 796.50Garbage billed for January 2015 105,519.12


CHK68036 02/13/2015 7448 CRC CUSTOMER SERVICE FOR AFTER HOURS 2,091.28CUSTOMER SERVICE FOR AFTER HOURS 522.82


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Check /Tran Date



CHK68037 02/13/2015 212 DAKOTA SUPPLY GROUP Acuity brands lighting 237.80

CHK68038 02/13/2015 25 ECM PUBLISHERS INC Advertising 408.00

CHK68039 02/13/2015 23 ELK RIVER MUNICIPAL UTILITIES ELECTRICITY: 13069 ORONO PKWY 1,044.50ELECTRICITY: 13069 ORONO PKWY 261.13ELECTRICITY: 1705 MAIN ST BY DAM 61.63ELECTRICITY: GARY ST WATER TOWER 36.37ELECTRICITY: UTILITIES GARAGE 1,220.37ELECTRICITY: 1705 MAIN ST POWER PLAN 47.03ELECTRICITY: 1705 MAIN ST POWER PLAN 3,596.24ELECTRICITY: 1697 MAIN ST 1,119.17ELECTRICITY: 268 ELK HILLS WATER BOO 92.19ELECTRICITY: WATER TOWER #3 137.46ELECTRICITY: WATER TOWER #3(REPEAT 37.16ELECTRICITY: 12955 MEADOWVALE RD W 129.27ELECTRICITY: WATER TOWER #4 44.46WELL & TOWER SECURITY MONITOR 4,365.92ELECTRICITY: HWY 169 LANDFILL 220.43ELECTRICITY: 1705 MAIN ST 62.79ELECTRICITY: WELL #3 1,368.98ELECTRICITY: HWY 169 LANDFILL 47.03ELECTRICITY: WELL #5 2,335.90ELECTRICITY: WELL #4 2,231.58ELECTRICITY: WELL #2 1,016.19ELECTRICITY: WELL #7 2,678.31ELECTRICITY: WELL #6 3,057.76ELECTRICITY: WELL #8 1,624.93ELECTRICITY: WELL #9 623.81


CHK68040 02/13/2015 122 ELK RIVER WINLECTRIC CO Items for main structure 85.38


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Check /Tran Date


Conservation IMP meter covers 106.64


CHK68041 02/13/2015 3993 EN POINTE TECHNOLOGIES iPad and folio 709.18

CHK68042 02/13/2015 671 FASTENAL COMPANY Supplies 133.72

CHK68043 02/13/2015 8949 FS3 INC. Fall Protection 7,002.48Fall Protction 68.73Fall Protection 330.84


CHK68044 02/13/2015 91 GOPHER STATE ONE-CALL Annual fee 50.00Annual fee 50.00January 2015 66.80January 2015 66.80


CHK68045 02/13/2015 5118 GRAND RENTAL STATION Spark plug 7.48

CHK68046 02/13/2015 4984 ANGELA HAUGE Health food for safety meetings 28.90Health food for safety meetings 7.22EXPENSES FOR WELLNESS SEMINAR 57.68


CHK68047 02/13/2015 21 HORWITZ NS/I Well station work 4,833.12

CHK68048 02/13/2015 6836 INNOVATIVE OFFICE SOLUTIONS, LLC Office supplies 173.04Office supplies 43.26


CHK68049 02/13/2015 48 LEAGUE OF MN CITIES INS TRUST Workers Compensation final audit 2,016.00Workers Compensation final audit 504.00


CHK68050 02/13/2015 5895 LLOYD LORENZEN Safety glasses 171.69

CHK68051 02/13/2015 188 MARTIES FARM SERVICE INC New chain 15.71

CHK68052 02/13/2015 145 MENARDS MISC PARTS & SUPPLIES 16.12


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Check /Tran Date


MISC PARTS & SUPPLIES 13.83MISC PARTS & SUPPLIES 219.99MISC PARTS & SUPPLIES 440.30MISC PARTS & SUPPLIES 9.03MISC PARTS & SUPPLIES 101.43MISC PARTS & SUPPLIES 70.46MISC PARTS & SUPPLIES 109.09MISC PARTS & SUPPLIES 46.48


CHK68053 02/13/2015 7445 MINNESOTA UNEMPLOYMENT INSURAN Benefits paid during quarter 4 2014 4,322.40Benefits paid during quarter 4 2014 1,080.60


CHK68054 02/13/2015 39 MMUA 2015 Meter School Thiry, Ross, Girtz 1,665.002015 Winter legislative conf-Al Nadeau 30.00


CHK68055 02/13/2015 120 NAPA AUTO PARTS PARTS & SUPPLIES 5.01PARTS & SUPPLIES 328.92PARTS & SUPPLIES 22.27


CHK68056 02/13/2015 43 NORTHERN TOOL Torque wrench 102.97

CHK68057 02/13/2015 622 OFFICE FURNITURE SOLUTIONS,INC Troy and Michelle's office 537.50

CHK68058 02/13/2015 4465 RAILROAD MANAGEMENT COMPANY III, rent - GRE Drive (3/1/15-2/28/16) 160.78

CHK68059 02/13/2015 8897 RALPHIE'S VICTORY LANE Fuel for chainsaw 2.80

CHK68060 02/13/2015 128 RANDY'S SANITATION, INC. Trash service 570.76Recycling service 18.07


CHK68061 02/13/2015 130 RESCO Bolts 374.06

CHK68062 02/13/2015 6575 ROGERS PRINTING Pay online insert 1,180.03


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Check /Tran Date


Redesign and printing rate sheet, energy 343.28Redesign and printing rate sheet, energy 225.28


CHK68063 02/13/2015 2560 SHERWIN- WILLIAMS CO. Paint 126.09Paint 63.05


CHK68064 02/13/2015 227 SHOE MENDERS & SADDLERY Workboots - Tony Hubbard 174.60

CHK68065 02/13/2015 7237 SUSA Annual registration fee 125.00

CHK68066 02/13/2015 7681 TOSHIBA FINANCIAL SERVICES LEASE FOR COPIER AT OFFICE 115.18LEASE FOR COPIER AT OFFICE 28.79


CHK68067 02/13/2015 90 TOTAL TOOL Crimper repair 274.35

CHK68068 02/13/2015 8186 TRANSAMERICA LIFE INS. CO. LTC 436.20

CHK68069 02/13/2015 8546 TWIN CITY HARDWARE Steel Door 245.81

CHK68070 02/13/2015 3360 UPS STORE #5093 Shipping 38.30

CHK68071 02/13/2015 345 UTILITY TRUCK SERVICES Truck #11 295.41

CHK68072 02/13/2015 2609 WASTE MANAGEMENT ERMU GAS GENERATOR SERVICE AGREE 31,613.33GAS PURCHASED 12,892.29


CHK68073 02/13/2015 3535 WATSON CO INC brown paper towel rolls 90.14Urinal De orderizer 24.29Toilet paper 105.40Muti-fold Towels 285.72Coffee Filters 32.02


CHK68074 02/13/2015 8214 WELCOME WAGON Gift books 157.50

CHK68075 02/13/2015 55 WESCO RECEIVABLES CORP. Transformer Tie Downs 115.96


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Check /Tran Date


CHK68076 02/13/2015 821 WHEELER WORLD INC. Inspection & evaluation w/ engine air up 7,486.59

CHK68077 02/13/2015 9344 AARON WHITE Travel meals 23.40

CHK68078 02/13/2015 1074 WINDSTREAM TELEPHONE 463.70TELEPHONE 115.92


CHK68079 02/13/2015 122 WINELECTRIC LED Lights For Office 3,438.70

CHK68080 02/13/2015 610 WRIGHT HENNEPIN INT'L RESPONSE CEN Security monitoring 2,794.80

CHK68081 02/13/2015 8213 ZIMMERMAN TODAY Advertising 148.00

CHK68083 02/13/2015 3405 POSTMASTER POSTAGE FOR PERMIT #38 4,000.00POSTAGE FOR PERMIT #38 1,000.00


CHK68084 02/27/2015 593 ABRA AUTOBODY & GLASS Truck #8 glass repair 250.00

CHK68085 02/27/2015 150 ALARM PRODUCTS DIST, INC Magnetic Base 62.05

CHK68086 02/27/2015 8372 ALARM.COM INCORPORATED WIRELESS SIGNAL FORWARDING 17.50

CHK68087 02/27/2015 522 ALTERNATIVE TECHNOLOGIES, INC PCB SAMPLING 130.00

CHK68088 02/27/2015 2920 BATTERIES PLUS BULBS BATTERIES 67.17

CHK68089 02/27/2015 6 BEAUDRY OIL COMPANY DIESEL FOR TRUCKS 615.19FUEL FOR TRUCKS 1,103.90


CHK68090 02/27/2015 8552 BECK LAW OFFICE LEGAL SERVICES - TRAVEL 40.25LEGAL SERVICES 1,000.00


CHK68091 02/27/2015 301 BLACK'S LINEMEN SUPPY, INC Lineman's Wrench 278.94

CHK68092 02/27/2015 428 BOYER TRUCKS PARTS FOR TRUCK #21 406.33RETURN PART FOR TRUCK #21 -182.73



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Check /Tran Date


CHK68093 02/27/2015 8843 CAMPBELL KNUTSON LEGAL SERVICES 108.50

CHK68095 02/27/2015 5838 COMFORT INN - PLYMOUTH ROOM CHARGE 160.92ROOM CHARGE 160.92


CHK68096 02/27/2015 32 CONNEXUS ENERGY PURCHASED POWER & SUBSTATION CRE -1,167.86PURCHASED POWER & SUBSTATION CRE 1,769,099.64

Total for Check/Tran - 68096: 1,767,931.78

CHK68097 02/27/2015 212 DAKOTA SUPPLY GROUP Antenna Whip 74.14Antenna Base 285.16


CHK68098 02/27/2015 7072 ELK RIVER AREA CHAMBER OF COMME SHOW EXPO BOOTH FEE 156.00SHOW EXPO BOOTH FEE 39.00


CHK68099 02/27/2015 122 ELK RIVER WINLECTRIC CO REPLACEMENT BALLAST FOR OLD SHOP 55.34LIGHT HARDWARE 22.20


CHK68100 02/27/2015 8709 FAIRVIEW DIAGNOSTIC LABORATORIES TESTING 242.00

CHK68101 02/27/2015 28 G & K SERVICES SERVICES MATS 84.27MATS 21.07


CHK68102 02/27/2015 606 THOMAS GEISER EXPENSES FOR FIRSTLINE SUPERVISION 61.88

CHK68103 02/27/2015 824 HOME DEPOT CREDIT SERVICES HOME DEPOT SUPPLIES 10.11HOME DEPOT SUPPLIES 2.32HOME DEPOT SUPPLIES 19.51


CHK68104 02/27/2015 8082 HYPERION INTEGRATOR INSTALL ALARM SYSTEM OFFSIGHT 4,088.13

CHK68105 02/27/2015 8047 JP MORGAN CHASE, N.A. REFUND #1808155 $211.72 169.38REFUND #1808155 $211.72 42.34


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Check /Tran Date



CHK68106 02/27/2015 48 LEAGUE OF MN CITIES INS TRUST CLAIM DEDUCTIBLE BILLING 267.03

CHK68107 02/27/2015 119 MINNESOTA COMPUTER SYSTEMS INC TOSHIBA E STUDIO COPIER LEASE 543.57TOSHIBA E STUDIO COPIER LEASE 135.8911x17 THICK PAPER 105.27


CHK68108 02/27/2015 202 MINNESOTA DEPT OF PUBLIC SAFETY HAZERDOUS CHEMICAL FEE - WELL 2 100.00HAZARDOUS CHEMICAL INVENTORY FEE 100.00HAZARDOUS CHEMICAL INV FEE WELL #4 100.00HAZARDOUS CHEMICAL INV FEE WELL #5 100.00HAZARDOUS CHEMICAL INV FEE WELL #6 100.00HAZARDOUS CHEMICAL INV FEE WELL # 100.00HAZARDOUS CHEMICAL INV FEE WELL # 100.00HAZARDOUS CHEMICAL INVENTORY FEE 25.00


CHK68109 02/27/2015 39 MMUA METERING TECH PROGRAM-T. HUBBARD 1,065.00

CHK68110 02/27/2015 3376 JEFF MURRAY EXPENSES FOR UMMA TRAINING 72.93

CHK68111 02/27/2015 573 NCPERS MINNESOTA EXTRA LIFE INSURANCE FOR ERMU EMPL 224.00

CHK68112 02/27/2015 43 NORTHERN TOOL 12 VOLT POWER UNIT 479.26

CHK68113 02/27/2015 9999 JAMAL OMAR DEPOSIT REFUND FOR 12935 MISSISSIPPI 179.69

CHK68114 02/27/2015 84 PERA FEE FOR PERA 8.00FEE FOR PERA 2.00


CHK68115 02/27/2015 3405 POSTMASTER POSTAGE FOR POSTAGE DUE ACCOUNT 400.00POSTAGE FOR POSTAGE DUE ACCOUNT 100.00


CHK68116 02/27/2015 9407 POWER PLAN OIB Bolts for Chipper knifes 58.69

CHK68117 02/27/2015 71 PRINCIPAL LIFE INSURANCE CO GRAND DENTAL, LIFE & LTD INSURANCE 4,259.43


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Check /Tran Date


DENTAL, LIFE & LTD INSURANCE 1,060.26DENTAL, LIFE & LTD INSURANCE 1,064.86


CHK68118 02/27/2015 6243 PROGRESSIVE BUSINESS PUBLICATIONS SUBSCRIPTION TO SUPV LEGAL UPDATE 286.27SUBSCRIPTION TO SUPV LEGAL UPDATE 71.57


CHK68119 02/27/2015 8897 RALPHIE'S VICTORY LANE FUEL FOR CHAINSAWS 2.70FUEL FOR BORE RIG 2.72


CHK68120 02/27/2015 9997 MILACA REALTY DEP To AP 250.00

CHK68121 02/27/2015 3219 RESOURCE TRAINING & SOLUTIONS/BCB HEALTH CARE PREMIUMS 8,660.25HEALTH CARE PREMIUMS 3,849.00HEALTH CARE PREMIUMS 2,886.75HEALTH CARE PREMIUMS 21,622.50HEALTH CARE PREMIUMS 9,610.00HEALTH CARE PREMIUMS 7,207.50HEALTH CARE PREMIUMS 614.81HEALTH CARE PREMIUMS 273.25HEALTH CARE PREMIUMS 204.94


CHK68122 02/27/2015 6575 ROGERS PRINTING BUSINESS CARDS 315.50BUSINESS CARDS 78.88BUSINESS CARDS 52.68BUSINESS CARDS 13.17


CHK68123 02/27/2015 8866 TONY ROSS EXPENSES FOR TRAINING 20.00

CHK68124 02/27/2015 7556 ROYAL SWITCHGEAR MFG CO. 15Kv 900A Subsation Blade 473.17

CHK68125 02/27/2015 87 SAVAGE TILE INSTALLATION, LLC. REPLACE TILES IN FRONT OF FRONT COU 320.00REPLACE TILES IN FRONT OF FRONT COU 80.00


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Check /Tran Date



CHK68126 02/27/2015 229 SHERBURNE COUNTY GOV. CENTER PROMISSORY NOTE & SECURITY AGREEM 15,959.00

CHK68127 02/27/2015 8467 SHERBURNE COUNTY GOVERNMENT CE LFG BONUS PAYMENT -2014 20,000.00

CHK68128 02/27/2015 20 SLACK PAINTING Painting Well #2 34,000.00

CHK68129 02/27/2015 6107 STUART C. IRBY CO. GLOVES AND GLOVE TESTING 784.37

CHK68130 02/27/2015 85 SUPERMATS, INC. 4-RUBBER MATS FOR FLOORS IN WELLS 147.49CUTTING MATS FOR WELLS 39.01


CHK68131 02/27/2015 8986 TELIT WIRELESS SOLUTIONS VIDEOFIED MONITORING SYSTEM 96.13

CHK68132 02/27/2015 8948 TRYCO LEASING INC. TOSHIBA COPIER LEASE 112.19TOSHIBA COPIER LEASE 28.05


CHK68133 02/27/2015 8381 VERIFIED CREDENTIALS BACKGROUND SCREENING 47.00

CHK68134 02/27/2015 86 WASTE MANAGEMENT-ELK RIVER LAND LFG BONUS PAYMENT -2014 21,336.40

CHK68135 02/27/2015 135 WATER LABORATORIES INC WATER TESTING - JAN 375.00

CHK68136 02/27/2015 55 WESCO RECEIVABLES CORP. Snap On Tools 288.51

CHK68137 02/27/2015 122 WINELECTRIC Light Cord 38.35High Bay LED Linemen shop 2,812.95Cord Connector 17.01


CHK68138 02/27/2015 8613 YP SECURITY ADVERTISING 115.00

Total for Bank Account - 1 : (140) 2,296,384.15


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02/01/2015 To 02/28/2015Bank Account: 2 - ELECTRIC/PAYROLL

Check /Tran Date


WIRE24 02/13/2015 50 AFFINITY PLUS CREDIT UNION AFFINITY CREDIT UNION 2,008.00

WIRE26 02/27/2015 50 AFFINITY PLUS CREDIT UNION AFFINITY CREDIT UNION 2,008.00

Total for Bank Account - 2 : (2) 4,016.00

Grand Total : (142) $ 2,300,400.15


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PARAMETERS ENTERED:

Check Date: 02/01/2015 To 02/28/2015Bank: All

Vendor: AllCheck: All

Journal: AllFormat: All GL References/Amounts

Extended Reference: NoCheck/TransactionSort By:

Voids: NoneAllPayment Type:NoGroup By Payment Type:

Minimum Amount: 0.00Authorization Listing: No

Authorization Comments: NoCredit Card Charges: No


Feb-15

SALES TAX 147,360.64

FED/FICA WITHHELD 51,220.41

STATE WITHHELD 8,435.16

DEF COMP 8,616.54

PERA 30,289.46

HEALTHCARE SAV PLAN 3,536.86

249,459.07

Electronic Transfers

20

Page 1

Regular meeting of the Elk River Municipal Utilities Commission

February 10, 2015

ELK RIVER MUNICIPAL UTILITIES

REGULAR MEETING OF THE

UTILITIES COMMISSION

HELD AT UTILITIES CONFERENCE ROOM

February 10, 2015

Members Present: John Dietz, Chair; Al Nadeau, Vice Chair; and Daryl Thompson, Trustee

ERMU Staff Present: Troy Adams, General Manager;

Theresa Slominski, Finance and Office Manager;

Eric Volk, Water Superintendent;

Wade Lovelette, Technical Services Superintendent;

Tom Sagstetter, Conservation & Key Accounts Manager;

Michelle Canterbury, Executive Administrative Assistant;

Others Present: Cal Portner, City Administrator; Peter Beck, Attorney

1.0 CALL MEETING TO ORDER

John Dietz called the February 10, 2015 meeting to order at 3:30 p.m.

1.1 Pledge of Allegiance

The Pledge of Allegiance was recited.

1.2 Consider Utilities Agenda

Troy Adams added Recognition of Employee Achievement to agenda item 1.3, and added

agenda item 5.5, Elk River Dam Failure Analysis Update to New Business.

Daryl Thompson moved to approve the amended February 10, 2015 Utilities agenda. Al

Nadeua seconded the motion. Motion carried 3-0.

1.3 Introduction of New Employee and Recognition of Employee Achievement

Theresa Slominski introduced the new Purchasing Specialist, Kelly Durland. Troy Adams

introduced Zac Johnson and announced that he just recently achieved his journeyman status.

The Commission welcomed the new employee and congratulated Zac on his achievement.

2.0 CONSENT AGENDA (Approved By One Motion)

John Dietz had a few questions on the financials, staff responded.

Al Nadeau moved to approve the Consent Agenda as follows:

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February 10, 2015

2.1 January Check Register

2.2 January 13, 2015 Previous Meeting Minutes

2.3 Financial Statements

2.4 2015 Pay Equity Report

Daryl Thompson seconded the motion. Motion carried 3-0.

3.0 OPEN FORUM

No one appeared for open forum.

4.0 OLD BUSINESS

4.1 Midwest Municipal Transmission Group and Transmission Ownership Update

In May 2006, the Utilities Commission authorized ERMU joining the Midwest Municipal

Transmission Group (MMTG) to explore the potential to obtain ownership in the regional

transmission system. The action to join MMTG represented ERMU’s decision to investigate a

change in direction towards ownership versus renting. Ownership in the transmission system

essentially works as a hedge to mitigate volatility in transmission costs.

Troy Adams announced that on January 31, 2015, ERMU received its first payment for their

share in the CAPX2020 Brookings transmission project in the amount of $72,741. This amount

represents the margin above the bond payments. ERMU will continue to receive payments for

their ownership in this transmission project for the 40 year life of the asset. This is a historic

moment in ERMU history. Central Minnesota Municipal Power Agency (CMMPA) will be

issuing a press release on this. There was further discussion.

5.0 NEW BUSINESS

5.1 2014 Annual Safety Report

Minnesota Rules Chapter 7826 Public Utilities Commission Electric Utility Standards

cover safety, reliability, service, and reporting requirements. Per 7826.0100(A), municipal

utilities are exempt from these requirements. However, the Elk River Municipal Utilities

(ERMU) Commission adopted a number of parts of this chapter as a Distribution

Reliability Standard policy. This policy includes an Annual Safety Report requirement.

The policy requires ERMU to “file an annual safety performance report with its local

governing body. The report will include summaries of all reports filed with OSHA and the

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February 10, 2015

Occupational Safety and Health Division of the Minnesota Department of Labor and

Industry during the calendar year.”

In 2014, ERMU only submitted one report that qualifies under this reporting requirement;

the OSHA Form 300A, which is a summary of work related first report of injuries and

illnesses. Troy Adams presented the OSHA Form 300A that had been filed. There were

only four recorded incidents and zero days lost from work. John Dietz asked if we would

be receiving some type of dividend on our workers compensation premiums. Staff

responded.

5.2 2014 Electric Reliability Report

Minnesota Rules Chapter 7826 Public Utilities Commission Electric Utility Standards

cover safety, reliability, service, and reporting requirements. Per 7826.0100(A), municipal

utilities are exempt from these requirements. However, the ERMU Commission adopted a

number of parts of this chapter as a Distribution Reliability Standard policy requiring

annual reporting on system reliability.

Wade Lovelette presented the 2014 Electric Reliability Report. In 2014, our reliability

numbers remained excellent. The reliability index numbers reflect the condition of our

robust electrical system as well as the superb response time from our local line crews. This

also reflects the local accountability, long term visioning on the system design, and

ongoing system maintenance. There was further discussion. The Commission requested

staff bring back a comparison of our utility with other public power utilities in our region.

5.3 Performance Metrics Update

Theresa Slominski presented the Performance Metrics fourth quarter update. Staff is on

target for all metrics except one; the CAIDI reliability metric. CAIDI is the average outage

duration, or average restoration time. The goal is 2 hours or less and we are just under 3

hours for the metric calculation. At the close of the fiscal 2014 year, and completion of the

audit, the final score card will be evaluated and presented to the Commission for awarding

the related incentive compensation in 2015. John Dietz had a question on what percentage

the bonus would be based on the preliminary score card. Staff responded.

5.4 2015 Minnesota Municipal Utilities Association Legislative Conference Update

Troy Adams distributed copies of the 2015 State Position Statements packet he received at

the Minnesota Municipal Utilities Association (MMUA) Legislative Conference. Troy

stated that one of the big topics was the Clean Power Plan (CCP). This is the EPA’s

published proposed rule intended to address climate change concerns. With the plan,

Minnesota would be required to reduce carbon by 41%. One of the problems with this is

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February 10, 2015

Minnesota wouldn’t get credit for being an early adopter of renewables installed between

2005 and 2012. The final version of the EPA’s rule is expected sometime in 2015. Only

when the rule is final can Minnesota begin on the development of its CCP plan. Based on

this, our action request to the state is to do nothing with the state laws until the CCP rule is

finalized.

Tom Sagstetter also attended the conference and wanted to add that even though the CCP

may not be crystal clear, we still need to come up with a plan. We need to be working

towards remediation of coal, and continuing to move towards conservation and renewable

energy. It may not be enforceable until 2019 but we need to be thinking how we’re going to

meet certain mandates. The other big message we were able to deliver to our local

representatives was, if they had questions about any energy policies, please reach out to us

or other local utilities. Another concern Tom brought up was that hydro is currently

excluded as a renewable resource in carbon reduction. With things that we may be looking

at doing in the future with hydro and the dam, it should count towards clean power and our

reduction in carbon.

Troy Adams briefly touched on other conference topics including: Women’s Economic

Security Act; OSHA updates; IPL-SMEC; and Service Territories. The Board of Directors

Meeting included a discussion on pay equity and lineworker wages. They also spent some

time talking about the 2015 American Public Power Association (APPA) National

Conference and the 2016 APPA Lineworkers Rodeo; both taking place in Minnesota.

5.5 Elk River Dam Failure Analysis Update

Troy Adams gave an update on the Dam Failure Analysis. For the past year we’ve been

working on updating the Emergency Action Plan (EAP) for the Elk River Dam. The EAP

was approved by both the Utilities Commission and City Council and was then submitted

to the Department of Natural Resources (DNR). Upon submission, the DNR requested

numerous changes that we’ve been working on. The DNR was willing to approve the EAP,

provided an updated Dam Failure Analysis (DFA) was completed in the near future. The

cost of a DFA would run approximately $11,800.

We were recently notified by the DNR that they had grant funds available that could be

used towards an updated DFA; they have secured a grant for $6,000. The city will need to

apply for the grant as they are the owner of the asset. Troy explained that we’ve added this

item to the agenda because we had been sharing the cost of the EAP with the city, and that

it would only seem fair to share the remaining cost to complete the DFA; approximately

$3,000 each. Staff requested the Commission approve the cost share with city to complete

the DFA. Daryl Thompson inquired as to where the $3,000 would come from. Staff

responded.

Daryl Thompson made a motion to approve the cost share for the Dam Failure

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February 10, 2015

Analysis (DFA) with the City of Elk River. Al Nadeau seconded the motion. Motion

carried 3-0.

6.0 OTHER BUSINESS

There was no other business.

6.1 Staff Updates

Troy Adams gave a quick update on the upcoming APPA Lineworkers Rodeo that will be held

in Sacramento California. We have three individuals that are interested and have committed to

go; Zac Johnson, Tony Ross and Aaron White. Mark Fuchs will also be attending the event and

serving as a judge. Troy Adams expressed an interest in attending the rodeo and wanted to run

it by the Commissioners to make sure they were on board. The Commissioners were in

consensus of Troy attending the event.

Troy Adams shared that Minnesota Municipal Power Agency (MMPA) were at Lincoln and

Meadowvale Elementary today giving presentations on Energy Savings. As part of membership

this is one of the things they come out and do; work in our school district.

Theresa Slominski gave an update on NISC. We went live as scheduled on February 2nd

. There

have been many challenges and NISC is working on a laundry list of items. Staff has done an

excellent job of working through things and keeping an upbeat attitude. While everything is not

perfect, we’re going to get there. We will have some grueling weeks ahead of us. There was

further discussion.

Wade Lovelette shared that Fratalone Excavating has finished dredging the cooling/discharge

pond. They will be back in the spring to dig up the discharge pipe and do some dress up work.

The excavator did a very nice job.

Eric Volk gave a recap on the private hydrant program. After sending out letters to the private

hydrant owners last November, we increased the amount of private hydrants we service from

129 to 159. We are now servicing 159 of the 205 private hydrants we have inventoried. In

addition, we annually service and maintain another 200 of our own hydrants. It has been a big

increase in workload for the water operators considering we were doing minimal maintenance

just a few years ago. John Dietz asked if we made a profit on the private hydrant program. Eric

Volk responded that at a minimum we break even. It’s more of a value added public service.

There was further discussion.

6.2 Set Date for Next Meeting

The next regularly scheduled Commission meeting will be cancelled due to a scheduling

conflict, and a special meeting will be held on March 17, 2015.

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February 10, 2015

The Commission recessed the regular meeting at 4:23 p.m.

6.3 Closing of Meeting: “Meeting to be Closed pursuant to MN Statute 13D.05, Subd.

3(c)(3) to develop or consider offers or counteroffers for the purchase or sale of real

or personal property.”

a. Call Closed Session to Order

b. Discussion

c. Adjourn Closed Session

6.4 Adjourn Regular Meeting

Al Nadeau moved to adjourn the regular meeting of the Elk River Municipal Utilities

Commission at 4:26 p.m. Daryl Thompson seconded the motion. Motion carried 3-0.

Minutes prepared by Michelle Canterbury.

___________________________

John J. Dietz

Chair, ERMU Commission

___________________________

Tina Allard

City Clerk

26

FINANCIAL INDEX

Jan-15 PAGE

P & L NARRATIVE ………….. 28

COMBINED BALANCE SHEET ………….. 30

ELECTRIC INCOME STATEMENT ………….. 31

WATER INCOME STATEMENT ………….. 33

GRAPH #1 ELECTRICAL PURCHASES ………….. 34

GRAPH #2 ELECTRIC SALES ………….. 35

GRAPH #3 ELECTRIC SALES/CUSTOMER CLASS ………….. 36

GRAPH #4 WATER PRODUCTION ………….. 37

GRAPH #5 WATER SALES ………….. 38

DETAILED ELECTRIC INCOME STATEMENT ………….. 39

………….. 40

………….. 41

………….. 42

………….. 43

………….. 44

DETAILED WATER INCOME STATEMENT ………….. 45

………….. 46

………….. 47

………….. 48

27

PROFIT AND LOSS NARRATIVE

(From Statement of Revenues, Expenses and Changes in Net Position)

January 2015

Electric P&L

January’s electric kwh sales are down from the prior year, 3.5%. For further breakdown:

Residential usage is down 9%

Small Commercial usage is down 2%

Large Commercial usage is down .45%

January Operating Revenue is increased 14% over the prior year, however there was a

PCA credit last year of $344,143 given to customers and so the comparison is skewed.

Factoring out the PCA credit from the prior year, the Revenue is down .2%, which is

more consistent with the decrease in kwh noted above.

Other Revenue is up slightly, 2%, from the prior year, with most items consistent to the

prior year. The exception is Landfill Gas Project (LFG), which is up 11% reflecting

better performance of the engines after the overhauls.

Overall, Total Revenues of $2,613,399 are above the prior year by 13.3%, and ahead of

budget by 8.1%.

Purchased Power of $1,764,495 is ahead of budget by 1.8%, and under the prior year by

5.4%.

For other expenses, in total they are under the prior year by 5.1% and over budget by

4.8%. The biggest impact is Depreciation which is now reflecting actual numbers and so

will grow each month as assets are added. Previously, this was a constant number for a

monthly distribution of an annual estimate.

For January 2015, the Electric Department has a Net Profit of $132,528 which is ahead of

our budget of $85,680, and ahead of the prior year Net Loss of ($289,848.)

28

Water P&L

January water usage is up 7% from the prior year. For further breakdown:

Residential use up 3.5 %

Commercial use up 9.9%

Water Operating Revenues for January are up from last year by 12% and better than

budget by 32%.

Other Revenues of $42,894 are double from the prior year, with the Connection Fees

being the driving force. As mentioned in other narratives, these revenues are very

unpredictable.

Overall, Total Revenues of $159,976 are ahead of the prior year by 28% and ahead of

year-to-date budget by 52%.

Expenses are over the prior year by 7.5% and over budget by 5.1%. The biggest impact is

a timing one with Dues and Subscriptions for the DNR Report that is filed annually. The

fees this year were $11,593, and last year this report was filed in early February (and the

related expense of $11,627 was also recognized in February.)

For January 2015, the Water Department has a Net Loss – expected this time of year – of

($78,730), which is above last year’s loss of ($94,077) and above the budgeted loss of

($123,117.)

29

COMBINED BALANCE SHEETJANUARY 2015

ELECTRIC WATERASSETSCURRENT ASSETS CASH & TEMPORARY INVESTMENTS 1,718,4968,185,313 ACCOUNTS RECEIVABLE 702,8593,406,893 INVENTORIES 15,712967,198 PREPAID ITEMS 35,302195,048 CONSTRUCTION IN PROGRESS 556,001191,377 TOTAL CURRENT ASSETS 3,028,37112,945,830

RESTRICTED ASSETS BOND RESERVE FUND 0490,500 EMERGENCY RESERVE FUND 1,149,4122,500,140 UNRESTRICTED RESERVE FUND 113,82438,884 TOTAL RESTRICTED ASSETS 1,263,2353,029,524

FIXED ASSETS PRODUCTION 11,143,740391,218 LFG PROJECT 03,804,327 TRANSMISSION 0710,988 DISTRIBUTION 21,910,55834,223,488 GENERAL 859,5997,577,540 FIXED ASSETS (COST) 33,913,89846,707,560 LESS ACCUMULATED DEPRECIATION (13,127,828)(20,196,265) TOTAL FIXED ASSETS, NET 20,786,06926,511,295

OTHER ASSETS AND DEFFERED OUTFLOWS (6,610)(75,124)

TOTAL ASSETS 25,071,06642,411,525

LIABILITIES AND FUND EQUITYCURRENT LIABILITIES ACCOUNTS PAYABLE 44,6653,211,765 SALARIES AND BENEFITS PAYABLE 107,011323,703 DUE TO CITY 0343,122 DUE TO OTHER FUNDS 00 BONDS PAYABLE-CURRENT PORTION 0390,000 UNEARNED REVENUE 61,9079,283 TOTAL CURRENT LIABLITIES 213,5834,277,872LONG TERM LIABILITIES LFG PROJECT 01,408,358 DUE TO COUNTY 020,000 BONDS PAYABLE, LESS CURRENT PORTION 1,849,6803,603,713 TOTAL LONG TERM LIABILITIES 1,849,6805,032,071

TOTAL LIABILITIES 2,063,2639,309,943

FUND EQUITY CAPITAL ACCOUNT CONST COST 0490,500 CONTRIBUTED CAPITAL 00 RETAINED EARNINGS 23,086,53232,478,554 NET INCOME (LOSS) (THROUGH PREVIOUS MONTH) (78,730)132,528 TOTAL FUND EQUITY 23,007,80233,101,582

TOTAL LIABILITIES & FUND EQUITY 25,071,06642,411,525

30

ELK RIVER MUNICIPAL UTILITESELK RIVER, MINNESOTA

STATEMENTS OF REVENUES, EXPENSES AND CHANGES IN NET POSITIONFOR PERIOD ENDING JANUARY 2015

2015JANUARY

2014JANUARY

2015YTD

2014YTD

2015 YTD

BUDGET2015 YTDBud Var%

2014 v. 2015Actual Var%

YTDVARIANCE

2015 ANNUALBUDGET

Electric

RevenueOperating Revenue Elk River 2,229,292 2,229,292 2,046,082 1,948,020 1,948,0209 1427,876,812 281,272 Elk River-City Donated 15,892 15,892 15,661 14,759 14,7591 8219,650 1,133 Otsego 182,931 182,931 181,447 166,448 166,4481 102,419,908 16,484 Rural Big Lake 17,297 17,297 19,302 16,908 16,908(10) 2219,471 389 Dayton 20,028 20,028 20,784 19,064 19,064(4) 5256,678 964 Public St & Hwy Lighting 30,387 30,387 32,011 29,315 29,315(5) 4386,861 1,073 Generation and Sub Station Credit 2,968 2,968 13,549 2,848 2,848(78) 441,175 120 Dispersed Generation Credit (66,220) (66,220) (79,051) (67,320) (67,320)(16) (2)(771,008) 1,100 Other Revenue/CIP/Rate Increase/AC Credit 0 0 0 0 00 0(50,000) 0

Total Operating Revenue 2,432,575 2,432,575 2,249,785 2,130,041 2,130,0418 1430,599,548 302,534

Other Operating Revenue Interest/Dividend Income 12,352 12,352 13,202 15,438 15,438(6) (20)105,000 (3,087) Customer Penalties 20,119 20,119 19,709 23,420 23,4202 (14)250,000 (3,302) LFG Project 89,202 89,202 102,805 80,411 80,411(13) 111,136,812 8,792 Connection Fees 9,425 9,425 2,604 10,515 10,515262 (10)125,000 (1,090) Security 31,014 31,014 25,084 29,110 29,11024 7270,000 1,904 Misc Revenue 18,712 18,712 3,748 18,223 18,223399 3125,720 489 Prior Period Adjustment 0 0 0 0 00 00 0

Total Other Revenue 180,824 180,824 167,152 177,117 177,1178 22,012,532 3,706

Total Revenue 2,613,399 2,613,399 2,416,937 2,307,159 2,307,1598 1332,612,080 306,240

Expenses Purchased Power 1,764,495 1,764,495 1,733,299 1,860,663 1,860,6632 (5)22,577,733 (96,168) Operating & Mtce Expense 16,207 16,207 15,947 26,107 26,1072 (38)327,422 (9,900) Landfill Gas 56,158 56,158 50,027 55,935 55,93512 0717,500 223 Distribution Expense 29,460 29,460 16,420 22,403 22,40379 32227,515 7,057 Maintenance Expense 62,906 62,906 8,178 63,653 63,653669 (1)947,770 (748) Depreciation 158,216 158,216 191,667 191,666 191,666(17) (17)2,300,000 (33,450) Interest Expense 12,040 12,040 12,117 16,682 16,682(1) (28)133,089 (4,642) Security 14,894 14,894 13,127 12,292 12,29213 21215,000 2,602 Other Operating Expense (870) (870) (729) 6,178 6,17819 (114)30,248 (7,048) Customer Accounts Expense 16,907 16,907 15,635 17,725 17,7258 (5)255,720 (818) Administrative & General Expense 241,676 241,676 176,256 226,821 226,82137 73,053,013 14,85531



2015JANUARY

2014JANUARY

2015YTD

2014YTD

2015 YTD



YTDVARIANCE

2015 ANNUALBUDGET

Total Expenses(before Operating Transfers) 2,372,090 2,372,090 2,231,944 2,500,125 2,500,1256 (5)30,785,010 (128,036)

Operating Transfer Transfer To City For 99 Bond 0 0 0 0 00 00 0 Operating Transfer/Other Funds 65,374 65,374 59,110 56,993 56,99311 15810,000 8,381 Utilities & Labor Donated 43,408 43,408 40,203 39,888 39,8888 9515,000 3,520

Total Operating Transfer 108,782 108,782 99,313 96,881 96,88110 121,325,000 11,901 Net Income Profit(Loss) 132,528 132,528 85,680 (289,848) (289,848)55 (146)502,070 422,375

32



2015JANUARY

2014JANUARY

2015YTD

2014YTD

2015 YTD



YTDVARIANCE

2015 ANNUALBUDGET

Water

RevenueOperating Revenue Water Sales 117,082 117,082 88,526 104,159 104,15932 122,193,576 12,923

Total Operating Revenue 117,082 117,082 88,526 104,159 104,15932 122,193,576 12,923

Other Operating Revenue Interest/Dividend Income 3,088 3,088 3,284 3,860 3,860(6) (20)26,700 (772) Customer Penalties 1,046 1,046 777 1,671 1,67135 (37)15,000 (625) Connection Fees 25,753 25,753 6,332 5,434 5,434307 374165,000 20,319 Misc Revenue 13,007 13,007 6,185 9,591 9,591110 36103,680 3,416 Restate Beginning Retained Earnings 0 0 0 0 00 00 0

Total Other Revenue 42,894 42,894 16,578 20,556 20,556159 109310,380 22,338

Total Revenue 159,976 159,976 105,104 124,715 124,71552 282,503,956 35,261

Expenses Production Expense 425 425 7,217 670 670(94) (37)20,000 (245) Pumping Expense 26,913 26,913 33,512 31,008 31,008(20) (13)449,600 (4,094) Distribution Expense 11,966 11,966 16,841 9,347 9,347(29) 28192,500 2,618 Depreciation 92,992 92,992 94,167 93,333 93,333(1) 01,130,000 (341) Interest Expense 5,937 5,937 6,426 7,343 7,343(8) (19)66,262 (1,406) Other Operating Expense 36 36 (263) 76 76(114) (53)(772) (40) Customer Accounts Expense 4,447 4,447 4,063 3,892 3,8929 1459,500 555 Administrative & General Expense 65,651 65,651 36,216 48,124 48,12481 36592,440 17,526

Total Expenses(before Operating Transfers) 208,366 208,366 198,179 193,792 193,7925 82,509,530 14,574

Operating Transfer Transfer To City For 99 Bond 30,000 30,000 30,000 25,000 25,0000 2030,000 5,000 Operating Transfer/Other Funds 0 0 0 0 00 00 0 Operating Transfer From City 0 0 0 0 00 00 0 Utilities & Labor Donated 339 339 42 0 0707 0500 339

Total Operating Transfer 30,339 30,339 30,042 25,000 25,0001 2130,500 5,339 Net Income Profit(Loss) (78,730) (78,730) (123,117) (94,077) (94,077)(36) (16)(36,074) 15,348

33

))

20

25

30

35

40

45

50

55

60

65

De

ma

nd

in

MW

Month

Elk River Municipal Utilities Monthly Electrical Demand

2014

2013

14,000

19,000

24,000

29,000

34,000

En

erg

y P

urc

ha

se

s i

n M

WH

Month

Elk River Municipal Utilities Monthly Energy Purchases

2013

2014

34

10,000

12,000

14,000

16,000

18,000

20,000

22,000

24,000

26,000

28,000

Ele

ctr

ic L

oad

in

MW

H

Month

Elk River Municipal Utilities Monthly Total Electric Load

2013

2014

$1,000,000

$1,500,000

$2,000,000

$2,500,000

$3,000,000

$3,500,000

Sa

les

in

Do

lla

rs

Month

Elk River Municipal Utilities Monthly Electric Sales

2013 2014

35

-

2,000

4,000

6,000

8,000

10,000

12,000

14,000

16,000

18,000

Lo

ad

s in

MW

H

Month

Elk River Municipal Utilities Monthly Residential, Commercial & Industrial Loads

Residential

Industrial

Commercial

2014

$0

$200,000

$400,000

$600,000

$800,000

$1,000,000

$1,200,000

$1,400,000

$1,600,000

$1,800,000

Sale

s i

n D

oll

ars

Month

Elk River Municipal Utilities Monthly Residential, Commercial & Industrial Sales

Residential

Commercial

2013

2014

Industrial

2013

36

0

20

40

60

80

100

120

140

Pu

mp

ag

e i

n M

illio

n G

al.

Month

Elk River Municipal Utilities Monthly Water Pumpage

2014

2013

0

1

2

3

4

5

6

Pe

ak

Da

y i

n M

illi

on

Ga

l.

Month

Elk River Municipal Utilities Peak Day Pumpage

2013

2014

37

0

20

40

60

80

100

120

140

Sa

les

in

Mil

lio

n G

al.

Month

Elk River Municipal Utilities Monthly Water Sales

2013

2014

$0

$50,000

$100,000

$150,000

$200,000

$250,000

$300,000

$350,000

$400,000

$450,000

Sale

s i

n D

ollars

Month

Elk River Municipal Utilities Monthly Water Sales

2014

2013

38



2015JANUARY

2014JANUARY

2015YTD

2014YTD

2015 YTD



YTDVARIANCE

2015 ANNUALBUDGET

Electric

RevenueOperating Revenue Elk River

ELECT SALES/ELK RIVER RES 836,906 836,906876,406 815,701876,406 7 5440.4411 9,981,317 39,500

ELECT SALES/ER NON-DEMAND 188,811 188,811217,742 177,810217,742 22 15440.4412 2,750,593 28,930

ELECT SALES/ER DEMAND 922,304 922,3041,135,145 1,052,5711,135,145 8 23440.4413 15,144,902 212,841

2,229,292 2,229,292 2,046,082 1,948,020 1,948,0209 14Total For Elk River: 27,876,812 281,272

Elk River-City DonatedELECT SALES/ER CITY DONATED 14,759 14,75915,892 15,66115,892 1 8440.4415 219,650 1,133

15,892 15,892 15,661 14,759 14,7591 8Total For Elk River-City Donated: 219,650 1,133

OtsegoELECT SALES/OTSEGO RES 87,845 87,84593,491 94,37493,491 (1) 6440.4416 1,178,976 5,646

ELECT SALES/OTSEGO NON-DEM 30,099 30,09934,775 30,96034,775 12 16440.4417 467,476 4,676

ELECT SALES/OTSEGO DEMAND 48,503 48,50354,665 56,11354,665 (3) 13440.4418 773,456 6,162

182,931 182,931 181,447 166,448 166,4481 10Total For Otsego: 2,419,908 16,484

Rural Big LakeELECT SALES/BIG LAKE RES 16,754 16,75417,170 19,22317,170 (11) 2440.4421 216,898 416

ELECT SALES/BL NON-DEMAND 154 154127 79127 61 (18)440.4422 2,573 (27)

17,297 17,297 19,302 16,908 16,908(10) 2Total For Rural Big Lake: 219,471 389

DaytonELECT SALES/DAYTON RES 16,701 16,70117,191 18,06417,191 (5) 3440.4431 220,728 490

ELECT SALES/DAYTON NON-DEM 2,363 2,3632,837 2,7202,837 4 20440.4432 35,950 474

20,028 20,028 20,784 19,064 19,064(4) 5Total For Dayton: 256,678 964

Public St & Hwy LightingELECT SALES/ELK RIVER SEC LTS 2,815 2,8154,038 2,6654,038 52 43440.4414 34,317 1,223

ELECT SALES/OTSEGO SEC LTS 829 8290 8370 (100) 0440.4419 10,224 (829)

ELECT SALES/BIG LAKE SEC LTS 155 1550 1600 (100) 0440.4424 2,022 (155)

ELECT SALES/DAYTON SEC LTS 402 4020 3840 (100) 0440.4434 4,612 (402)

PUBLIC ST & HWY LIGHTING/CIT 25,115 25,11526,349 27,96526,349 (6) 5440.4441 335,685 1,235

30,387 30,387 32,011 29,315 29,315(5) 4Total For Public St & Hwy Lighting: 386,861 1,073

Generation and Sub Station CreditSUB-STATION CREDIT 1,168 1,1681,168 1,1681,168 0 0440.4550 14,015 0

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GENERATION CREDIT 1,680 1,6801,800 12,3811,800 (85) 7440.4551 20,160 120

2,968 2,968 13,549 2,848 2,848(78) 4Total For Generation and Sub Station Credit: 41,175 120

Dispersed Generation CreditDISPERSED GENERATION CREDIT (67,320) (67,320)(66,220) (79,051)(66,220) (16) (2)440.4552 (771,008) 1,100

(66,220) (66,220) (79,051) (67,320) (67,320)(16) (2)Total For Dispersed Generation Credit: (771,008) 1,100

Other Revenue/CIP/Rate Increase/AC Credit0 0 0 0 00 0Total For Other Revenue/CIP/Rate Increase/AC Cred (50,000) 0

Total Operating Revenue2,130,041 2,130,0412,432,575 2,249,7852,432,575 8 1430,599,548 302,534

Other Operating Revenue Interest/Dividend Income

INTEREST & DIVIDEND INCOME 15,438 15,43812,352 13,20212,352 (6) (20)460.4691 105,000 (3,087)

12,352 12,352 13,202 15,438 15,438(6) (20)Total For Interest/Dividend Income: 105,000 (3,087)

Customer PenaltiesCUSTOMER DELINQUENT PENALT 23,420 23,42020,119 19,70920,119 2 (14)470.4701 250,000 (3,302)

20,119 20,119 19,709 23,420 23,4202 (14)Total For Customer Penalties: 250,000 (3,302)

LFG ProjectLFG PROJECT 80,411 80,41189,202 102,80589,202 (13) 11470.4721 1,136,812 8,792

89,202 89,202 102,805 80,411 80,411(13) 11Total For LFG Project: 1,136,812 8,792

Connection FeesDISCONNECT & RECONNECT CHA 10,515 10,5159,425 2,6049,425 262 (10)470.4702 125,000 (1,090)

9,425 9,425 2,604 10,515 10,515262 (10)Total For Connection Fees: 125,000 (1,090)

SecuritySECURITY REVENUE 29,110 29,11031,014 25,08431,014 24 7470.4700 270,000 1,904

31,014 31,014 25,084 29,110 29,11024 7Total For Security: 270,000 1,904

Misc RevenueMISC ELEC REVENUE - TEMP CHG 0 0150 0150 0 0470.4703 1,000 150

NON-UTILITY OPERATIONS 6,239 6,23912,123 012,123 0 94470.4715 65,000 5,884

MISC NON-UTILITY 9,924 9,9244,332 3,7484,332 16 (56)470.4722 35,000 (5,592)

SALES OF MERCHANDISE 0 0225 0225 0 0470.4724 0 225

RENTAL PROPERTY INCOME 2,060 2,0601,882 01,882 0 (9)470.4750 24,720 (178)

18,712 18,712 3,748 18,223 18,223399 3Total For Misc Revenue: 125,720 489

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0 0 0 0 00 0Total For Prior Period Adjustment: 0 0

Total Other Revenue177,117 177,117180,824 167,152180,824 8 22,012,532 3,706

180,824 180,824 167,152 177,117 177,1178 2Total For Total Other Revenue: 2,012,532 3,706

2,307,159 2,307,1592,613,399 2,416,9372,613,399 8 13 Total Revenue 32,612,080 306,240

Expenses Purchased Power

PURCHASED POWER 1,860,663 1,860,6631,764,495 1,733,2991,764,495 2 (5)540.5551 22,577,733 (96,168)

1,764,495 1,764,495 1,733,299 1,860,663 1,860,6632 (5)Total For Purchased Power: 22,577,733 (96,168)

Operating & Mtce ExpenseOPERATING SUPERVISION 5,295 5,2950 3,5550 (100) 0540.5461 89,342 (5,295)

DIESEL OIL FUEL 1,832 1,8320 1,5800 (100) 0540.5471 23,000 (1,832)

NATURAL GAS 3,023 3,0233,307 5,3203,307 (38) 9540.5472 38,000 284

STATION PWR & WTR CONSP/PLA 4,447 4,4474,887 3,9524,887 24 10540.5483 50,000 439

OTHER EXP/PLANT SUPPLIES-ETC 206 206222 1,163222 (81) 8540.5484 6,000 16

MISC OTHER PWR GENERATION E 730 73014 56214 (98) (98)540.5491 13,000 (717)

MAINTENANCE OF STRUCTURE/P 3,465 3,4653,803 1,8743,803 103 10540.5521 32,525 339

MTCE OF ENGINES/GENERATORS- 2,909 2,9092,404 (3,328)2,404 (172) (17)540.5531 43,555 (505)

MTCE OF PLANT/LAND IMPROVE 4,199 4,1991,569 1,2691,569 24 (63)540.5541 32,000 (2,630)

16,207 16,207 15,947 26,107 26,1072 (38)Total For Operating & Mtce Expense: 327,422 (9,900)

Landfill GasLFG PURCHASED GAS 13,134 13,13412,892 13,46712,892 (4) (2)550.5050 170,000 (242)

LANDFILL GAS O&M 41,055 41,05541,613 31,86641,613 31 1550.5051 500,000 559

LFG ADMIN 352 352267 3,417267 (92) (24)550.5052 10,000 (85)

LFG INSURANCE 1,394 1,3941,385 1,2771,385 8 (1)550.5053 17,500 (9)

56,158 56,158 50,027 55,935 55,93512 0Total For Landfill Gas: 717,500 223

Distribution ExpenseTRANSFORMER EX/OVERHD & UN 1,537 1,537214 216214 (1) (86)580.5831 11,000 (1,323)

METER EXP - REMOVE & RESET 93 930 690 (100) 0580.5861 4,000 (93)

TEMP SERVICE-INSTALL & REMO 145 145158 125158 26 9580.5871 1,500 13

MISC DISTRIBUTION EXPENSE 20,629 20,62929,088 16,01029,088 82 41580.5881 203,515 8,459

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29,460 29,460 16,420 22,403 22,40379 32Total For Distribution Expense: 227,515 7,057

Maintenance ExpenseMTCE OF STRUCTURES 92 92338 299338 13 267590.5911 7,500 246

MTCE OF SUBSTATIONS 2,005 2,0051,180 2,4531,180 (52) (41)590.5921 20,000 (825)

MTCE OF SUBSTATION EQUIPME 319 319672 0672 0 111590.5922 10,000 353

MTCE OF OVERHD LINES/TREE TR 8,169 8,1698,894 12,5258,894 (29) 9590.5931 135,000 725

MTCE OF OVERHD LINES/STANDB 1,652 1,6521,900 1,2811,900 48 15590.5932 30,000 247

MTCE OF OVERHEAD 2,672 2,67218,134 2,62618,134 591 579590.5933 97,120 15,462

MTCE OF UNDERGROUND/DISTRI 4,409 4,4091,716 (23,981)1,716 (107) (61)590.5941 97,525 (2,693)

LOCATE UNDERGROUND PRIMAR 1,126 1,1261,062 5541,062 92 (6)590.5943 26,000 (64)

MTCE OF LINE TRANSFORMERS 1,474 1,474888 787888 13 (40)590.5951 35,000 (587)

MTCE OF STREET LIGHTING 1,441 1,4414,558 1,3664,558 234 216590.5961 35,000 3,117

MTCE OF SECURITY LIGHTING 250 2501,964 121,964 16,267 686590.5962 12,000 1,713

MTCE OF METERS 7,238 7,2386,646 4,1026,646 62 (8)590.5971 85,515 (591)

VOLTAGE COMPLAINTS 0 065 22065 (70) 0590.5972 8,000 65

SALARIES/TRANS & DISTRIBUTIO 2,446 2,4460 1,6450 (100) 0590.5981 43,575 (2,446)

ELECTRIC MAPPING 3,538 3,5386,512 2,3216,512 181 84590.5985 67,000 2,974

MTCE OF OVERHEAD SERVICE/2N 1,054 1,0540 1,0710 (100) 0590.5991 13,000 (1,054)

MTCE OF UNDERGROUND ELEC S 1,586 1,5861,126 4201,126 168 (29)590.5992 37,020 (460)

LOCATE UNDERGROUND SECOND 989 989717 539717 33 (28)590.5993 22,000 (273)

TRANSPORTATION EXPENSE 23,192 23,1926,533 (62)6,533 (10,637) (72)590.5995 166,515 (16,658)

62,906 62,906 8,178 63,653 63,653669 (1)Total For Maintenance Expense: 947,770 (748)

DepreciationDEPRECIATION 191,666 191,666158,216 191,667158,216 (17) (17)595.8031 2,300,000 (33,450)

158,216 158,216 191,667 191,666 191,666(17) (17)Total For Depreciation: 2,300,000 (33,450)

Interest ExpenseINTEREST ON BONDS/LONG TERM 16,955 16,95512,313 12,39012,313 (1) (27)596.8071 136,360 (4,642)

INTEREST ON DEFEASED BONDS (273) (273)(273) (273)(273) 0 0596.8075 (3,271) 0

12,040 12,040 12,117 16,682 16,682(1) (28)Total For Interest Expense: 133,089 (4,642)

SecuritySECURITY EXPENSE 12,292 12,29214,894 13,12714,894 13 21597.8172 215,000 2,602

14,894 14,894 13,127 12,292 12,29213 21Total For Security: 215,000 2,602

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Other Operating ExpenseLOSS ON DISPOSITION OF PROP 5,871 5,8710 00 0 0597.8213 20,000 (5,871)

OTHER DONATIONS 0 00 220 (100) 0597.8263 5,000 0

DAM MAINTENANCE EXPENSE 0 0141 0141 0 0597.8264 7,800 141

AMORTIZATION OF DEBT DISCOU 0 0(1,159) (796)(1,159) 46 0597.8281 (9,552) (1,159)

INTEREST PD ON METER DEPOSIT 4 44 44 0 0597.8341 1,000 0

RENTAL PROPERTY EXPENSE 303 303144 41144 251 (52)597.8400 6,000 (159)

(870) (870) (729) 6,178 6,17819 (114)Total For Other Operating Expense: 30,248 (7,048)

Customer Accounts ExpenseMETER READING EXPENSE 1,486 1,4863,536 1,1973,536 195 138900.9021 35,000 2,050

COLLECTING EXP DISC/RECONNE 306 306308 218308 41 1900.9030 12,000 2

CUSTOMER CHECKS RETURNED - 0 00 1,4660 (100) 0900.9041 1,500 0

MISC CUSTOMER ACCTS EXP-CO 16,066 16,06614,362 11,43214,362 26 (11)900.9051 162,220 (1,704)

CUST BLGS NOT PD/SENT FOR CO (132) (132)(1,300) 1,322(1,300) (198) 885900.9061 45,000 (1,167)

16,907 16,907 15,635 17,725 17,7258 (5)Total For Customer Accounts Expense: 255,720 (818)

Administrative & General ExpenseSALARIES/OFFICE & COMMISSION 35,656 35,65639,953 20,32339,953 97 12920.9201 659,295 4,296

TEMPORARY STAFFING 0 00 3330 (100) 0920.9205 4,000 0

OFFICE SUPPLIES & EXPENSE 11,145 11,14510,564 8,58810,564 23 (5)920.9211 110,000 (581)

LT & WATER CONSUMPTION/OFFI 877 8771,044 8921,044 17 19920.9212 25,000 168

BANK CHARGES 472 472220 1,590220 (86) (53)920.9213 4,000 (252)

LEGAL FEES 31 310 3,3530 (100) 0920.9221 40,000 (31)

AUDITING FEES 2,560 2,5602,560 4,1702,560 (39) 0920.9231 14,400 0

INSURANCE 15,147 15,14713,725 15,97013,725 (14) (9)920.9241 176,866 (1,422)

UTIL SH OF MEDICAL/DENTAL/DI 60,017 60,01763,961 46,06563,961 39 7920.9261 525,936 3,944

UTILITY SHARE OF PERA 20,629 20,62921,328 14,27921,328 49 3920.9262 192,000 699

UTILITY SHARE OF FICA 19,792 19,79219,555 13,76919,555 42 (1)920.9263 192,000 (237)

EMPLOYEES SICK PAY 6,385 6,38512,997 4,35212,997 199 104920.9264 96,768 6,612

EMP VACATION/HOLIDAY PAY 25,684 25,68436,015 8,84336,015 307 40920.9266 230,000 10,331

CONSERVATION IMP PROGRAM 9,414 9,414(6,812) 8,700(6,812) (178) (172)920.9269 186,454 (16,226)

ENVIRONMENTAL COMPLIANCE 1,812 1,8122,019 2,1892,019 (8) 11920.9281 27,000 208

CONSULTING FEES 138 1380 00 0 0920.9291 85,000 (138)

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TELEPHONE 1,593 1,5931,686 1,3441,686 25 6920.9301 22,000 93

ADVERTISING 0 00 1130 (100) 0920.9302 5,500 0

DUES & SUBSCRIPTIONS - FEES 7,079 7,0796,023 15,3506,023 (61) (15)920.9303 200,000 (1,056)

TRAVEL EXPENSE 1,407 1,40723 023 0 (98)920.9304 15,500 (1,384)

SCHOOLS & MEETINGS 6,984 6,98416,796 6,03316,796 178 140920.9305 177,294 9,812

MISC GENERAL EXPENSE 0 019 019 0 0920.9306 1,000 19

241,676 241,676 176,256 226,821 226,82137 7Total For Administrative & General Expense: 3,053,013 14,855

Total Expenses(before Operating Transfers)2,500,125 2,500,1252,372,090 2,231,9442,372,090 6 (5)30,785,010 (128,036)

Operating Transfer Transfer To City For 99 Bond Operating Transfer/Other Funds

TRANSFER TO CITY 3% ER REVEN 56,993 56,99365,374 59,11065,374 11 15597.8262 810,000 8,381

65,374 65,374 59,110 56,993 56,99311 15Total For Operating Transfer/Other Funds: 810,000 8,381

Utilities & Labor DonatedUTILITIES & LABOR DONATED 39,888 39,88843,408 40,20343,408 8 9597.8261 515,000 3,520

43,408 43,408 40,203 39,888 39,8888 9Total For Utilities & Labor Donated: 515,000 3,520

Total Operating Transfer96,881 96,881108,782 99,313108,782 10 121,325,000 11,901

108,782 108,782 99,313 96,881 96,88110 12Total For Total Operating Transfer: 1,325,000 11,901

(289,848) (289,848)132,528 85,680132,528 55 (146) Net Income Profit(Loss) 502,070 422,375

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Water

RevenueOperating Revenue Water Sales

WATER SALES COMM & RES/COM 104,159 104,159116,742 88,526116,742 32 12610.6101 2,193,576 12,583

WATER SALES CITY DONATED 0 0339 0339 0 0610.6115 0 339

117,082 117,082 88,526 104,159 104,15932 12Total For Water Sales: 2,193,576 12,923

Total Operating Revenue104,159 104,159117,082 88,526117,082 32 122,193,576 12,923

117,082 117,082 88,526 104,159 104,15932 12Total For Total Operating Revenue: 2,193,576 12,923

Other Operating Revenue Interest/Dividend Income

INTEREST & DIVIDEND INCOME 3,860 3,8603,088 3,2843,088 (6) (20)460.4691 26,700 (772)

3,088 3,088 3,284 3,860 3,860(6) (20)Total For Interest/Dividend Income: 26,700 (772)

Customer PenaltiesCUSTOMER PENALTIES 1,671 1,6711,046 7771,046 35 (37)620.6301 15,000 (625)

1,046 1,046 777 1,671 1,67135 (37)Total For Customer Penalties: 15,000 (625)

Connection FeesWATER/ACCESS/CONNECTION FE 2,821 2,82123,915 5,84923,915 309 748620.6401 150,000 21,094

MISC CONNECTION FEES 2,613 2,6131,838 4831,838 281 (30)620.6402 15,000 (775)

25,753 25,753 6,332 5,434 5,434307 374Total For Connection Fees: 165,000 20,319

Misc RevenueRENTAL PROPERTY INCOME 515 515470 0470 0 (9)470.4750 6,180 (45)

MISCELLANEOUS REVENUE 535 5350 00 0 0620.6403 2,500 (535)

HYDRANT MAINTENANCE PROGR 0 0810 583810 39 0620.6404 7,000 810

WATER TOWER LEASE 8,541 8,54111,727 5,60211,727 109 37620.6406 88,000 3,186

13,007 13,007 6,185 9,591 9,591110 36Total For Misc Revenue: 103,680 3,416

Restate Beginning Retained Earnings0 0 0 0 00 0Total For Restate Beginning Retained Earnings: 0 0

Total Other Revenue20,556 20,55642,894 16,57842,894 159 109310,380 22,338

42,894 42,894 16,578 20,556 20,556159 109Total For Total Other Revenue: 310,380 22,338

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124,715 124,715159,976 105,104159,976 52 28 Total Revenue 2,503,956 35,261

Expenses Production Expense

MTCE OF STRUCTURES 207 207425 7,217425 (94) 105700.7021 20,000 218

TOWER & GROUNDS INSPECTION 463 4630 00 0 0700.7022 0 (463)

425 425 7,217 670 670(94) (37)Total For Production Expense: 20,000 (245)

Pumping ExpenseSUPERVISION 747 7470 8960 (100) 0710.7101 20,600 (747)

SUPPLIES & EXPENSE 21,226 21,22616,081 18,90616,081 (15) (24)710.7181 250,000 (5,145)

SAMPLING 698 698216 (521)216 (141) (69)710.7182 9,000 (482)

CHEMICAL FEED 1,731 1,7311,620 5,2171,620 (69) (6)710.7183 30,000 (111)

MTCE OF ELECT PUMPING EQUIP 0 032 032 0 0710.7201 0 32

MTCE OF WELLS 5,666 5,6668,963 8,1148,963 10 58710.7220 125,000 3,297

GENERATION 12 120 00 0 0710.7225 0 (12)

SCADA - PUMPING 926 9260 9000 (100) 0710.7230 15,000 (926)

26,913 26,913 33,512 31,008 31,008(20) (13)Total For Pumping Expense: 449,600 (4,094)

Distribution ExpenseMTCE OF WATER MAINS 926 926457 423457 8 (51)730.7301 60,000 (470)

LOCATE WATER SVC 49 49262 48262 446 435730.7309 7,500 213

LOCATE WATER MAIN 29 2945 045 0 55730.7310 0 16

MTCE OF WATER SERVICES 1,389 1,3894,512 04,512 0 225730.7311 0 3,123

WATER METER SERVICE 29 29274 215274 27 845730.7312 5,000 245

INSTALL & MTC IRRIG METERS 86 860 8200 (100) 0730.7315 5,000 (86)

MTCE OF CUSTOMERS SERVICE 4,282 4,2821,660 1,2061,660 38 (61)730.7321 31,000 (2,622)

WATER MAPPING 213 213155 124155 25 (27)730.7325 18,000 (59)

SCADA - DISTRIBUTION 741 7410 00 0 0730.7330 0 (741)

MTCE OF WATER HYDRANTS 0 0369 48369 669 0730.7331 25,000 369

MISC WATER EXPENSE/INVENTO 0 0106 305106 (65) 0730.7341 12,000 106

WAGES/WATER 374 3740 00 0 0730.7391 0 (374)

TRANSPORTATION EXPENSE (94) (94)4,126 (17)4,126 (24,371) (4,489)730.7395 15,000 4,220

GENERAL EXP/WATER PERMIT 1,323 1,3230 13,6690 (100) 0730.7399 14,000 (1,323)

11,966 11,966 16,841 9,347 9,347(29) 28Total For Distribution Expense: 192,500 2,618

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DepreciationDEPRECIATION 93,333 93,33392,992 94,16792,992 (1) 0595.8031 1,130,000 (341)

92,992 92,992 94,167 93,333 93,333(1) 0Total For Depreciation: 1,130,000 (341)

Interest ExpenseINTEREST ON BONDS/LONG TERM 7,411 7,4116,005 6,4946,005 (8) (19)596.8071 67,080 (1,406)

INTEREST ON DEFEASED BONDS (68) (68)(68) (68)(68) 0 0596.8075 (818) 0

5,937 5,937 6,426 7,343 7,343(8) (19)Total For Interest Expense: 66,262 (1,406)

Other Operating ExpenseRENTAL PROPERTY EXPENSE 76 7636 1036 260 (53)597.8400 2,500 (40)

2010 GO BONDS AMORT DISCOUN 0 00 (273)0 (100) 0750.7581 (3,272) 0

36 36 (263) 76 76(114) (53)Total For Other Operating Expense: (772) (40)

Customer Accounts ExpenseMETER READING EXPENSE 266 266162 329162 (51) (39)900.9021 7,000 (104)

COLLECTING EXP DISC/RECONNE 0 00 5420 (100) 0900.9030 6,500 0

MISC CUSTOMER ACCTS EXP-CO 3,626 3,6264,285 3,1924,285 34 18900.9051 45,000 659

4,447 4,447 4,063 3,892 3,8929 14Total For Customer Accounts Expense: 59,500 555

Administrative & General ExpenseSALARIES/OFFICE & COMMISSION 8,923 8,9239,738 4,2159,738 131 9920.9201 141,000 815

TEMPORARY STAFFING 0 00 1670 (100) 0920.9205 2,000 0

OFFICE SUPPLIES & EXPENSE 2,685 2,6856,840 3,1786,840 115 155920.9211 35,000 4,154

LT & WATER CONSUMPTION/OFFI 219 219261 178261 47 19920.9212 5,000 42

BANK CHARGES 62 6260 8360 (28) (3)920.9213 1,000 (2)

LEGAL FEES 0 00 6960 (100) 0920.9221 5,500 0

AUDITING FEES 640 640640 1,042640 (39) 0920.9231 3,600 0

INSURANCE 2,311 2,3111,939 4,8271,939 (60) (16)920.9241 44,216 (373)

UTIL SH OF MEDICAL/DENTAL/DI 17,383 17,38315,502 10,99715,502 41 (11)920.9261 121,423 (1,880)

UTILITY SHARE OF PERA 1,934 1,9342,526 1,6252,526 55 31920.9262 32,007 592

UTILITY SHARE OF FICA 1,918 1,9182,462 1,5522,462 59 28920.9263 23,083 544

EMPLOYEES SICK PAY 1,596 1,5962,960 1,0232,960 189 85920.9264 24,162 1,364

EMP VACATION/HOLIDAY PAY 6,421 6,4217,938 1,9227,938 313 24920.9266 46,535 1,517

MISCELLANEOUS - WELLHEAD P 0 00 5320 (100) 0920.9268 9,064 0

CONSERVATION IMP PROGRAM 535 5350 650 (100) 0920.9269 10,000 (535)

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ENVIRONMENTAL COMPLIANCE 197 1970 220 (100) 0920.9281 750 (197)

TELEPHONE 397 397422 311422 36 6920.9301 5,100 24

ADVERTISING 224 2240 6790 (100) 0920.9302 5,272 (224)

DUES & SUBSCRIPTIONS - FEES 1,231 1,23112,127 55812,127 2,073 885920.9303 39,249 10,896

TRAVEL EXPENSE 1 10 00 0 0920.9304 2,500 (1)

SCHOOLS & MEETINGS 1,446 1,4462,234 2,5442,234 (12) 54920.9305 23,479 787

MISC GENERAL EXPENSE 0 03 03 0 0920.9306 500 3

65,651 65,651 36,216 48,124 48,12481 36Total For Administrative & General Expense: 592,440 17,526

Total Expenses(before Operating Transfers)193,792 193,792208,366 198,179208,366 5 82,509,530 14,574

Operating Transfer Transfer To City For 99 Bond

TRANSFER TO CITY FOR 99 BOND 25,000 25,00030,000 30,00030,000 0 20597.8260 30,000 5,000 Operating Transfer/Other Funds Operating Transfer From City Utilities & Labor Donated

WATER AND LABOR DONATED 0 0339 0339 0 0597.8261 0 339

UTILITIES & LABOR DONATED 0 00 420 (100) 0790.8261 500 0 Total Operating Transfer

25,000 25,00030,339 30,04230,339 0 2130,500 5,339

30,339 30,339 30,042 25,000 25,0001 21Total For Total Operating Transfer: 30,500 5,339

(94,077) (94,077)(78,730) (123,117)(78,730) (36) (16) Net Income Profit(Loss) (36,074) 15,348

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UTILITIES COMMISSION MEETING

TO:

Elk River Municipal Utilities Commission

John Dietz – Chair

Al Nadeau – Vice Chair

Daryl Thompson – Trustee

FROM:

Wade Lovelette – Technical Services

Superintendent

MEETING DATE: March 17, 2015

AGENDA ITEM NUMBER: 4.1

SUBJECT:

2014 Electric Reliability Report (Revised)

BACKGROUND:

Minnesota Rules Chapter 7826 Public Utilities Commission Electric Utility Standards cover

safety, reliability, service, and reporting requirements. Per 7826.0100(A), municipal utilities are

exempt from these requirements. However, the Elk River Municipal Utilities Commission

adopted a number of parts of this chapter as a Distribution Reliability Standard policy requiring

annual reporting on system reliability.

DISCUSSION:

After Last month’s report of our reliability numbers, it was brought to our attention that some of

the outages reported to the American Public Power Association (APPA) had the wrong customer

count in them. After sending them the corrected data, some of our reliability numbers changed,

although our CAIDI number stayed close to the same. I have attached APPA’s eReliability

Tracker 2014 Annual Report. Even though the primary uses of reliability statistics are for self-

evaluation, utilities can use these statistics to compare with data from similar utilities. I was

unable to get MMUA’s comparisons because other municipals were unwilling to share their

results.

In 2014, our reliability index numbers remain excellent. These reliability index numbers reflect

the condition of our robust electrical system as well as the superb response time from our local

line crews. This also reflects the local accountability, long term visioning on system design, and

ongoing system maintenance. The table below reflects the number of customer outage minutes

from 2005 through 2014.

Year # of Customers # of Outage Minutes # of Outages

2005 8398 558,140 59

2006 8804 314,510 73

2007 9163 67,845 47

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2008 9067 155,768 57

2009 9170 46,706 49

2010 9207 526,144 77

2011 9576 297,359 51

2012 9285 71,496 57

2013 9285 55,451 31

2014 9426 243,965 44

A number of reliability indexes are used in the electric industry to make it easier to compare

performance of electric utilities. Listed below are the reliability indexes along with ERMU’s

2013 and 2014 statistics. Also included are APPA’s published averages that can be used by

utilities to better understand the performance of their electric system relative to other utilities

nationally and to those within their region or size class.

Average Service Availability Index (ASAI)

ASAI is a measure of the average availability of the sub-transmission and distribution systems to serve customers. It is the ratio of the total customer minutes that service was available to the total customer minutes available in a time period. This is normally expressed as a percentage.

ERMU’s 2014 ASAI is 99.9945% Availability ERMU’s 2013 ASAI was 99.999% Availability

Our utility's ASAI: 99.9945 Average ASAI for Utilities Within our Region 99.9894 Average ASAI for Utilities Within our Customer Size Class 99.9834

Customer Average Interruption Duration Index (CAIDI)

CAIDI is defined as the average duration (in minutes) of an interruption experienced by customers during a specific time frame. It is calculated by summing the customer minutes off during each interruption in the time period and dividing this by the number of customers experiencing one or more sustained interruptions during the time period. The resulting unit is minutes. The index enables utilities to report the average duration of a customer outage for those customers affected.

ERMU’s 2014 CAIDI is 199.883 minutes ERMU’s 2013 CAIDI was 118.23 minutes

Our utility's CAIDI: 199.8838 Average CAIDI for Utilities Within our Region 95.2256 Average CAIDI for Utilities Within our Customer Size Class 107.7752

System Average Interruption Duration Index (SAIDI)

SAIDI is defined as the average interruption duration for customers served during a specified time period. It is determined by summing the customer minutes off for each interruption during a specified time period and dividing that sum by the average number of customers served during that period. The

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unit is minutes. This index enables the utility to report how many minutes’ customers would have been out of service if all customers were out at one time.

ERMU’s 2014 SAIDI is 28.54 minutes ERMU’s 2013 SAIDI was 5.97 minutes

Our utility's SAIDI: 28.54 Average SAIDI for Utilities Within our Region 55.49 Average SAIDI for Utilities Within our Customer Size Class 87.14

System Average Interruption Frequency Index (SAIFI)

SAIFI is defined as the average number of times that a customer is interrupted during a specified time period. It is determined by dividing the total number of customers interrupted in a time period by the average number of customers served. The resulting unit is “interruptions per customer.”

ERMU’s 2014 SAIFI is 0.1428 ERMU’s 2013 SAIFI was 0.0505

Our utility's SAIFI: 0.143 Average SAIFI for Utilities Within our Region 0.817 Average SAIFI for Utilities Within Your Customer Size Class 0.839

Another statistic staff gets concerned about is the average length of any outage. Elk River

Municipal Utilities’ 2014 average length of outage was 131.07 minutes. In 2013 the average

length of outage was 116.84 minutes. Electric utilities with a high percentage of underground

facilities will exhibit higher length of outage time than electric utilities with more overhead

facilities.

Staff reviews these statistics in detail to find ways to continually improve our system. These

statistics are very good compared to other utilities. In 2014, birds and animals caused the greatest

number of outages resulting in 31.25% of our outage incidents. Outages resulting from branches

and/or trees made up 2.08% of our outage incidents. This low percentage is a reflection of the

good tree trimming our crews do during the winter. Other contributing factors include:

underground faults 16.67%; dig-ins, etc. 6.25%; component failure 4.17%; transformer failure

4.17%; fuse failure 10.42%; connector failure 12.50%; vehicle vs. pole 10.42%; and weather

related outages accounted for 2.08% of the incidents.

Many investor owned and cooperative run utilities “storm normalize “ their reliability numbers

by removing “major outages” due to storms from their reliability index number calculations.

Our reliability numbers have not been storm normalized. Our numbers reflect these major

outages and represent what our customer actually experienced in 2014. Overall, our electric

distribution system is robust and our reliability is very high.

ACTION REQUESTED:

No action is required.

ATTACHMENT:

American Public Power Association’s eReliablity Tracker 2014 Annual Report

51

Reliability reflects historic and ongoing engineering investment decisions within a utility. Proper use of reliability metrics ensures that the utility is not only performing its intended function, but also is providing service in a consistent and effective manner. Even though the primary use of reliability statistics is for self-evaluation, utilities can use these statistics to compare with data from similar utilities. However, differences such as electrical network configuration, ambient environment, weather conditions, and number of customers served typically limit most utility-to-utility comparisons. Due to the diverse range of utilities that use the eReliability Tracker, this report endeavors to group utilities by size and region to improve comparative analyses while reducing differences. Since this report contains overall data for all utilities that use the eReliability Tracker, it is important to consider the effect that a particularly large or small utility can have on the rest of the data. To ease the issues associated with comparability, reliability statistics are calculated for each utility with their respective customer weight taken into account prior to being aggregated with other utilities. All utilities are equally weighted and all statistics are developed on a per customer basis.

The aggregate statistics displayed in this report are calculated from utilities that experienced more than two outages in 2014. Also, utilities that experienced no outages this year, or did not upload any data, will have None/Null values in their report for their utility-specific data and were not included in the aggregate analysis.

The aggregate statistics provided in the following sections of the report are based on approximately 17,606 outages from 143 utilities, that recorded more than two outages for 2014 during the time period of analysis.


2014 Annual Report

I. General Overview

The eReliability Tracker Annual Report was created by the American Public Power Association to assist utilities in their efforts to understand and analyze their electric system. This report focuses on distribution system reliability across the country and is customized to each utility’s system. The data used to generate this report reflect activity in the eReliability Tracker from January 1, 2014 to December 31, 2014. Note that if you currently do not have a full year of data in the system, this analysis may not properly reflect your utility's statistics since it only includes data recorded for your utility as of February 24, 2015; therefore, any changes made after that date are not represented in this report.

52

13

42

32

12

50

9

2417

10

2

0

10

20

30

40

50

60

1 2 3 4 5 6 7 8 9 10

APPA Region

Count

of

Utilit

ies

Table 1

Customer size range per customer size class

Figure 1

Number of eRT utilities per APPA region

Your utility belongs to customer size class and region .3 3

To limit the comparison of utilities of truly different sizes, this report separates utilities into groups according to their number of customers served. In Table 1, the customer size distribution of utilities that use the eReliability Tracker is split into fifths to create five distinct customer size classes.

Since the utilities considered in this report represent a wide variety of locations across the United States, each utility is grouped with all others located in their corresponding APPA region. Figure 1 shows the number of utilities using the eReliability Tracker in each APPA region and Figure 2 displays the current United States map of APPA regional divisions.

Class 1:

Class 2:

Class 3:

Class 4:

Class 5:

0 -3,600

3,600 - 6,265

6,265 - 10,220

20,364- 1,481,735

10,220 - 20,364

Figure 2

Map of APPA Regions as of January 1, 2014

2

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II. IEEE Statistics

When using reliability metrics, a good place to start is with the industry standard metrics found in the IEEE 1366 guide. For each individual utility, the eReliability Tracker performs IEEE 1366 calculations for System Average Interruption Duration Index (SAIDI), System Average Interruption Frequency Index (SAIFI), Customer Average Interruption Duration Index (CAIDI), Momentary Average Interruption Frequency Index (MAIFI) and Average Service Availability Index (ASAI).

When collecting the necessary data for reliability indices, utilities often take differing approaches. Some utilities prefer to include information as detailed as circuit type or phases impacted, while others include only the bare minimum required. In all cases, the more details a utility provides, the more practical their analysis will be. As a basis for calculating these statistics in the eReliability Tracker, the following are required to create an outage in the system:

-Total number of customers served on the day of the outage-Time and date when the outage began -Primary cause of outage-Address where the outage was located

It is important to note that the time when the outage ended is not required in case the outage is ongoing; therefore, outages without end dates at the time of the report analysis are not included in the indices that measure duration, such as SAIDI and CAIDI. However, they are included in the calculations measuring interruption frequencies, such as SAIFI or MAIFI, as well as in the analysis of outage causes.

Due to the differences in how some utilities analyze major events (MEs) relative to their base statistics, it is important to note how they are calculated and used in this report. An example of a major event could be severe weather, such as a tornado or thunderstorm, which can lead to unusually long outages in comparison to your distribution system's typical outage. In the eReliability Tracker and in this report, the APPA major event threshold is used, which is a calculation based directly on outage events, rather than event days. The major event threshold allows a utility to remove outages that exceed the IEEE 2.5 beta threshold for events. The threshold takes into account the utility's past outage history up to 10 years in order to make this calculation. In the eReliability Tracker, if a utility does not have at least 36 outage events prior to the year being analyzed, no threshold is calculated; therefore, the field below showing your utility's threshold will be blank and the calculations without MEs in the SAIDI section of this report will be the same as the calculations with MEs for your utility. More outage history will provide a better threshold for your utility.

Your utility's major event threshold is (minutes).

If you wish to remove major events, the threshold calculated above is important to note because it impacts your SAIDI analysis. For the next year, based on your utility's outage history, any event with a SAIDI greater than minutes is considered as a major event and can be removed in your analysis.

The tables in this section can be used by utilities to better understand the performance of their electric system relative to other utilities nationally and to those within their region or size class. In the SAIDI section, indices are calculated for all outages with and without major events; furthermore, the data are broken down to show calculations for scheduled and unscheduled outages. For each of the reliability

If there is no major event threshold calculated for your utility, these fields are left blank and the calculations in this report including Major Events and excluding them will be the same. Your utility must have at least 36 outage events recorded in the eReliability Tracker in order to calculate a Major Event Threshold.

1

1

3

54

Your utility's SAIDI: 28.5464

64.6299

175.5715

55.4969

102.863 101.8402 107.517192.1373

41.2235

281.861

00

50

100

150

200

250

300

1 2 3 4 5 6 7 8 9 10

APPA Regions

Ave

rag

e S

AID

I (m

inu

tes)

Average eReliability Tracker Utility SAIDI 111.6347

Average SAIDI for Utilities Within Your Region 55.4969

Average SAIDI for Utilities Within Your Customer Size Class 87.1486

Minimum Value 0.2461

First Quartile (25th percentile) 18.6824

Third Quartile (75th percentile) 97.2444

Median Quartile (50th percentile) 50.4729

Maximum Value 3128.437

Figure 3

Average SAIDI for all utilities that use the eReliability Tracker per region

System Average Interruption Duration Index (SAIDI)

Since SAIDI is a sustained interruption index, only outages lasting longer than five minutes are included in the calculations. SAIDI is calculated by dividing the sum of all customer interruption durations within the specified time frame by the average number of customers served during that period. For example, a utility with 100 customer minutes of outages and 100 customers would have a SAIDI of 1.

Note that in the tables below, scheduled and unscheduled calculations include major events.

0

6.2962

2.7015

3.6156

28.5464

105.3348

52.7954

83.5351

0.2461

18.6751

47.6868

91.815

2974.7748

0

0

0.0146

0.701

308.3812

Unscheduled ScheduledAll

Unscheduled ScheduledAll

Table 3

Summary statistics of the SAIDI data compiled from the eReliability Tracker

Table 2

Average SAIDI for all utilities that use the eReliability Tracker (with and without MEs), belong to

your region, and are grouped in your customer size class

28.5464

67.8888

34.7555

47.955

No MEs

0.2461

11.2111

25.1516

56.433

3128.437

No MEs

SAIDI is defined as the average interruption duration (in minutes) for customers served by the utility system during a specific time period.

4

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Your utility's SAIFI: 0.1428

0.3925

1.411

0.8170.9556

0.7453

1.0836 1.0366

0.5899

1.5575

00

0.2

0.4

0.6

0.8

1

1.2

1.4

1.6

1.8

1 2 3 4 5 6 7 8 9 10

APPA Regions

Ave

rag

e S

AIF

I

Average eReliability Tracker Utility SAIFI 0.9615

Average SAIFI for Utilities Within Your Region 0.817

Average SAIFI for Utilities Within Your Customer Size Class 0.8387





Maximum Value 20

Figure 4

Average SAIFI for all utilities that use the eReliability Tracker per region

System Average Interruption Frequency Index (SAIFI)

Since SAIFI is a sustained interruption index, only outages lasting longer than five minutes are included in the calculations. SAIFI is calculated by dividing the total number of customer interruptions by the average number of customers served during that time period. For example, a utility with 150 customer interruptions and 200 customers would have a SAIFI of .75 interruptions per customer.

Table 5

Summary statistics of the SAIFI data compiled from the eReliability Tracker

Table 4

Average SAIFI for all utilities that use the eReliability Tracker, belong to your region, and are

grouped in your customer size class

SAIFI is defined as the average number of instances a customer on the utility system will experience an interruption during a specific time period.

5

56

149.5293

94.0484 95.2256 93.3338

133.5417

102.9167

87.241374.8117

162.7736

00

20

40

60

80

100

120

140

160

180

1 2 3 4 5 6 7 8 9 10

APPA Regions

Ave

rag

e C

AID

I (m

inu

tes)

Figure 5

Average CAIDI for all utilities that use the eReliability Tracker per region

Customer Average Interruption Duration Index (CAIDI)

Since CAIDI is a sustained interruption index, only outages lasting longer than five minutes are included in the calculations. It is calculated by dividing the sum of all customer interruption durations during that time period by the number of customers that experienced one or more interruptions during that time period. This metric reflects the average customer experience (minutes of duration) during an outage.

Your utility's CAIDI: 199.8838

Average eReliability Tracker Utility CAIDI 108.8292

Average CAIDI for Utilities Within Your Region 95.2256

Average CAIDI for Utilities Within Your Customer Size Class 107.7752






Table 6

Average CAIDI for all utilities that use the eReliability Tracker, belong to your region, and are


Table 7

Summary statistics of the CAIDI data compiled from the eReliability Tracker

CAIDI is defined as the average duration (in minutes) of an interruption experienced by customers during a specific time frame.

6

57

Your utility's MAIFI: 0.0001

0.0032

0.2015

0.7759

0.6227

0.506

0.1877

0.8642

0.4083

0.209

00

0.1

0.2

0.3

0.4

0.5

0.6

0.7

0.8

0.9

1

1 2 3 4 5 6 7 8 9 10

APPA Regions

Ave

rag

e M

AIF

I

Average eReliability Tracker Utility MAIFI 0.463

Average MAIFI for Utilities Within Your Region 0.7759

Average MAIFI for Utilities Within Your Customer Size Class 0.3692

Minimum Value 0

First Quartile (25th percentile) 0


Median Quartile (50th percentile) 0


Figure 6

Average MAIFI for all utilities that use the eReliability Tracker per region

Momentary Average Interruption Frequency Index (MAIFI)

In this report, an outage with a duration of less than five minutes is classfied as momentary. The index is calculated by dividing the total number of momentary customer interruptions by the total number of customers served by the utility. Momentary outages can be more difficult to track and many smaller utilities may not have the technology to do so; therefore, some utilities may have a MAIFI of zero below.

Table 9

Summary statistics of the MAIFI data compiled from the eReliability Tracker

Table 8

Average MAIFI for all utilities that use the eReliability Tracker, belong to your region, and are


MAIFI is defined as the average number of times a customer on the utility system will experience a momentary interruption.

7

58

Your utility's ASAI (%): 99.994568

99.987703

99.966655

99.989441

99.980429 99.980624 99.97954399.98247

99.992156

99.953908

99.93

99.94

99.95

99.96

99.97

99.98

99.99

100

1 2 3 4 5 6 7 8 9 10

APPA Regions

Ave

rag

e A

SA

I (%

)

Average eReliability Tracker Utility ASAI 99.979141

Average ASAI for Utilities Within Your Region 99.989441

Average ASAI for Utilities Within Your Customer Size Class 99.98347






Figure 7

Average ASAI for all utilities that use the eReliability Tracker per region

Average Service Availability Index (ASAI)

This load-based index represents the percentage availability of electric service to customers within the time period analyzed. It is caclulated by dividing the total hours service is available to customers by the total hours that service is demanded by the customers.

Table 11

Summary statistics of the ASAI data compiled from the eReliability Tracker

Table 10

Average ASAI for all utilities that use the eReliability Tracker, belong to your region, and are


ASAI is defined as a measure of the average availability of the sub-transmission and distribution systems that serve customers.

8

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2013 Energy Information Administration (EIA) Form 861 Data

EIA surveys electric power utilities annually through EIA Form 861 to collect electric industry data and subsequently make that data available to the public. In 2014, EIA began requesting reliability statistics in their survey from utility participants; therefore, APPA included EIA reliability statistics in this report for informational purposes. Please note that the following data includes investor-owned, rural cooperative, and public power utilities that were large enough to be required to fill out the full EIA 861, not the EIA 861-S form (for smaller entities). In addition, since the collection and release of EIA form data lags by more than a year, the data provided is based on 2013 data only. Therefore, it is suggested that the aggregate statistics contained herein be used only as an informational tool for further comparison of reliability statistics.

In the table, if an entity calculates SAIDI, SAIFI, and determines major event days in accordance with the IEEE 1366-2003 or IEEE 1366-2012 standard, they are included under the "IEEE Method" columns. If the entity calculates these values via another method, they are included under the "Other Method" columns.

There were approximately 965 utilities that submitted reliability data to the EIA. Additionally, it looks as though a number of utilities submitted incorrect data, which shows itself most in the average SAIFI numbers. For more general information on reliability metrics you can see APPA’s website at http://publicpower.org/reliability. Although EIA collected other reliability related data, the tables below only include SAIDI and SAIFI data. The full set of data can be downloaded at this link:

Table 13

Summary statistics of the SAIFI data compiled from 2013 data collected by EIA

Form EIA-861 collects information on the status of electric power industry participants involved in the generation, transmission, distribution, and sale of electric energy in the United States, its territories, and Puerto Rico.

Table 12

Summary statistics of the SAIDI data compiled from 2013 data collected by EIA

All No MEDs All No MEDs

IEEE Method Other Method

All No MEDs All No MEDs

IEEE Method Other Method

139.3246

Minimum Value

First Quartile (25th percentile)

Third Quartile (75th percentile)

Median Quartile (50th percentile)

Maximum Value

Average 249.4246 136.5727210.5557

0.00000.0000 0.00000.0000

42.000053.5000 6.000020.0000

88.0000128.0000 50.500071.0000

145.0250249.5000 112.0000169.0000

10,983.000010,983.0000 10,726.000012,944.0000

13.5847

Minimum Value

First Quartile (25th percentile)

Third Quartile (75th percentile)

Median Quartile (50th percentile)

Maximum Value

Average 15.2657 4.14042.5339

0.00000.0000 0.00000.0000

0.67780.8400 0.18180.3443

1.00001.2300 0.76951.0000

1.61502.0000 1.39251.9455

2,335.00002,837.0000 674.000087.0000

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III. Outage Causes

In general, sustained outages are the most commonly tracked outage type. In many analyses of sustained outages, utilities tend to exclude scheduled outages, partial power, customer-related problems, and qualifying major events from their reliability indices calculations. While this is a valid method for reporting, these outages should be included for internal review to make utility-level decisions. In this section, we evaluate common causes of sustained outages for your utility, corresponding region, and for all utilities that use the eReliability Tracker. It is important to note that in this report, sustained outages are classified as outages that last longer than five minutes, as defined by IEEE 1366.

Sustained Outage Causes

Equipment failure, extreme weather events, wildlife and vegetation are some of the most common causes of electric system outages. However, certain factors, such as regional weather and animal/vegetation patterns, can make a different set of causes more prevalent to a specific group of utilities. The following sections of this report include graphs depicting common causes of outages for your individual utility, all utilities in your region, and all utilities using the eReliability Tracker. The charts containing aggregate information are customer-weighted to account for differences in utility size for a better analytical comparison. For example, a particularly large utility will have a large number of outages compared to a small utility; in order to not have the collective information be more representative of the large utility, the number of occurrences is divided by customer size to account for the differences. In the figures below, the data represent the number of occurrences for each group of 1000 customers. For instance, a customer-weighted occurrence rate of "1" means 1 outage of that outage cause per 1000 customers on average in 2013.

Note that the sustained outage cause analysis is more comprehensive than the momentary outage cause analysis due to a bigger and more robust sample size for sustained outages. Regardless, tracking both sustained and momentary outages helps utilities understand and reduce outages. To successfully use the outage information tracked by your utility, it is imperative to classify and record outages in detail. The more information provided per outage, the more conclusive and practical your analyses will be.

10

61

1.7031

1.35371.2082

1.1305 1.1208

0

0.5

1

1.5

2

Outage Cause Types

Occu

rre

nce

Ra

tes

Figure 9

Top five customer-weighted causes of sustained outages for your utility

Figure 10

Top five customer-weighted occurrence rates for sustained outage causes in your region

1.2731

0.63650.5304

0.42440.3183

0

0.2

0.4

0.6

0.8

1

1.2

1.4

Outage Cause Types

Occu

rre

nce

Ra

tes

Squirrel Vehicle Accident Electrical Failure Wildlife Equipment Damage

2

2

Wildlife Squirrel Natural Equipment Weather

Figure 8

Top five customer-weighted occurrence rates for common causes of sustained outages for all

utilities that use the eReliability Tracker System

2.1579

1.4197 1.4116

1.08820.9371

0

0.5

1

1.5

2

2.5

Trees Human Weather Squirrel Unknown

Outage Causes Types

Occu

rre

nce

Ra

tes

2

Tree Squirrel Equipment Unknown Electrical Failure

For each utility, the number of occurrences for each cause is divided by that utility's customer size (in 1000s) to create an occurence rate that can be compared across different utility sizes.

2

11

62

0.1061

0 0 0 00

0.02

0.04

0.06

0.08

0.1

0.12

Outage Cause Types

Occu

rre

nce

Ra

tes

0.1695

0.0345 0.0345 0.0333 0.0305

0

0.02

0.04

0.06

0.08

0.1

0.12

0.14

0.16

0.18

Trees Human Weather Squirrel Unknown

Outage Cause Types

Occu

rre

nce

Ra

tes

Momentary Outage Causes

Figure 11

Top five customer-weighted occurrence rates for common causes of momentary outages for all

utilities that use the eReliability Tracker System

The ability to track momentary outages can be difficult or unavailable on some systems, but due to the hazard they pose for electronic equipment, it is important to track and analyze their causes. In this section, we evaluate common causes of momentary outages for your utility, region and customer size class as well as common causes for all utilities that use the eReliability Tracker. Utilities with less than eight momentary outages recorded in the eReliability Tracker as of January 27, 2014 are not included in the following analysis of momentary outage causes. Please note that only outages lasting less than five minutes are classified as momentary, as defined by IEEE 1366.

2

Unknown Squirrel Storm Weather Natural

Figure 12

Top five customer-weighted causes of momentary outages for your utility2, 3

Contractor-Dig-In None None None None

If your utility has less than eight momentary outages recorded in the eReliability Tracker, this graph will be blank.3

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0.5046

0.1553 0.1407 0.1262 0.1262

0

0.1

0.2

0.3

0.4

0.5

0.6

Outage Cause Types

Occu

rre

nce

Ra

tes

Figure 13

Top five customer-weighted occurrence rates for momentary outage causes in your region2

Thank you for using the eReliability Tracker and we hope this report is useful to your utility in analyzing your system. If you have any questions regarding the material provided in this report, please contact:

Tanzina IslamEnergy and Environmental [email protected]

Alex HofmannDirector, Energy and Environmental Services [email protected]

Michael J. HylandSenior Vice President, Engineering [email protected]

The eReliability Tracker was funded by a grant from the Demonstration of Energy & Efficiency Developments (DEED) Program.

Copyright 2015 by the American Public Power Association. All rights reserved.

Unknown Repairs Storm Natural Utility Human Error

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Page 1 of 1


TO:





FROM:

Troy Adams, P.E. – General Manager



SUBJECT:

Electric Cable Bid

BACKGROUND:

The underground electric cable required for the 2015 capital construction projects and

maintenance has been determined and noticed for formal bids.

DISCUSSION:

The bid opening was scheduled for March 2, 2015. The bid tabulation has been included.

ACTION REQUESTED:

Staff will make an award recommendation at the time of the meeting.

ATTACHMENT:

2015 Bid Tabulation for Electric Cable

65

2015 Elk River Municipal Bid Sheet

Footage Description Border States Irby Dakota Supply Resco Wesco Graybar FS3

11927 53rd st. NE 980 Lone Oak Rd. 2601 3rd Ave. N. 4100 30th Ave. S. 5151 Industrial Blvd. 2300 E. 25th St. 9030 64th st.

Albertville, MN 55301 Egan, MN 55121 Fargo, ND 58102 Morrhead, MN 56561 Fridley, MN 55421 Minneapolis, MN 55406 Annandale, MN 55302

Bid Bond/Notarized Yes/Yes Yes/Yes Yes/Yes Yes/Yes Yes/No Yes/Yes Yes/Yes

32,000 1000 KCMIL

Manufacturer General Okonite Okonite Kerite CME Superior

Delivery 11 weeks Stock As Required 8 weeks 16 weeks 5 weeks

Reel size 2000 Ft. +/- 5% 2000 Ft. 2000 Ft. +/-5% 2000 Ft. 1000 Ft. 1000 Ft.

Losses

Unit Price Firm $7.06 $7.50 $7.38 $7.49 $8.89

Total Price Firm $225,923.20 $240,096.00 $236,192.00 $0.00 $239,631.04 $284,398.40

Unit Price Esc $6.88 $7.50 $7.38 $8.71 $7.23 $8.40

Total Price Esc $220,008.00 $240,096.00 $236,192.00 $278,720.00 $231,277.76 $268,746.24

7,500 4/0 15Kv

Manufacturer General Okonite Okonite Kerite CME Superior


Reel size 2500 Ft. +/-5% 2500 Ft. 2500 Ft. +/-5% 2500 Ft. 2500 Ft. 1000 Ft.

Losses

Unit Price Firm $2.45 $2.21 $2.18 $2.34 $2.51

Total Price Firm $18,337.95 $16,575.00 $16,312.50 $0.00 $17,583.90 $18,799.58

Unit Price Esc $2.41 $2.21 $2.18 $2.62 $2.28 $2.51

Total Price Esc $18,054.00 $16,575.00 $16,312.50 $19,684.50 $17,107.58 $18,861.98

25,000 1/0 15Kv

Manufacturer General Okonite Okonite Hendrix CME Superior


Reel size 2500 Ft. +/-5% 2500 Ft. 2500 Ft. +/-5% 2500 Ft. 1000 Ft. 1000 Ft.

Losses

XLPE Unit Price Firm $1.77 $2.13

XLPE Total Price Frim $44,351.25 $0.00 $0.00 $0.00 $53,372.75

XLPE Unit Price Esc $1.69 $1.89 $2.05

XLPE Total Price Esc $42,183.00 $47,250.00 $51,244.50

EPR Unit Price Firm $2.11 $1.92 $1.89 $1.89

EPR Total Price Firm $52,866.25 $48,025.00 $47,250.00 $0.00 $47,272.00 $0.00

EPR Unit Price Esc $2.08 $1.92 $1.89 $1.82

EPR Total Price Esc $51,962.25 $48,025.00 $47,250.00 $0.00 $45,452.25 $0.00

3,000 #6 Duplex Border States Irby Dakota Supply Resco Wesco Graybar FS3

Manufacturer General Southwire King Wire General CME Superior


Reel size 1000 Ft. +/- 5% 1000 Ft. 1000 Ft. 1000 Ft. 1000 Ft. 1000 Ft.

Losses

Unit Price Firm $0.32 $0.35 $0.33 $0.26 $0.34

Total Price Firm $965.67 $0.00 $1,050.00 $994.83 $769.98 $1,014.54

Unit Price Esc $0.31 $0.33 $0.31 $0.25 $0.34

Total Price Esc $921.90 $990.00 $0.00 $932.64 $762.60 $1,014.54

19,000 2/0 Triplex

Manufacturer General Southwire King Wire Gerneral CME Superior

Delivery 9 weeks 6-8 weeks As Required 8 weeks 16 weeks 5 weeks

Reel size 1000 Ft. +/-5% 1000 Ft. 1000 Ft. 1000 Ft. 1000 Ft. 1000 Ft.

Losses

Unit Price Firm $0.93 $0.92 $0.94 $1.03 $0.99

Total Price Firm $17,693.75 $0.00 $17,537.00 $17,917.19 $19,627.38 $18,853.13

Unit Price Esc $0.90 $0.91 $0.91 $1.02 $0.99

Total Price Esc $17,074.35 $17,290.00 $0.00 $17,326.48 $19,315.59 $18,853.13

9,000 4/0 Triplex

Manufacturer General Southwire King Wire General CME Superior


Reel size 1000 Ft. +/-5% 1000 Ft. 1000 Ft. 1000 Ft. 1000 Ft. 1000 Ft.

Losses

Unit Price Firm $1.32 $1.27 $1.34 $1.29 $1.61

Total Price Firm $11,859.75 $0.00 $11,430.00 $12,031.11 $11,652.57 $14,513.40

Unit Price Esc $1.21 $1.23 $1.23 $1.29 $1.61

Total Price Esc $10,931.40 $11,070.00 $0.00 $11,098.44 $11,652.57 $14,513.40

30,500 Corrugated Pipe

Manufacturer Petro Flex Petro Flex Endot Dura Line Dura Line Endot Endot

Delivery 3 weeks Stock 2-3 weeks 2 weeks 2-3 week 5 weeks 2-3 weeks

Reel size 250 Ft. 250 Ft. 250 Ft. 250 Ft. 250 Ft. 100 Ft. 250 Ft.

Unit Price Firm $0.37 $0.38 $0.37 $0.38 $0.40 $0.38 $0.35

Total Price Firm $11,374.37 $11,590.00 $11,214.85 $11,498.50 $12,047.50 $11,492.40 $10,675.00

Unit Price Esc

Total Price Esc $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 $0.00

Border States Irby Dakota Supply Resco Wesco Graybar FS3

EPR Total Cable PriceFirm $327,646.57 $304,696.00 $329,771.50 $30,943.13 $336,536.87 $337,579.05

EPR Total Price Esc $318,951.90 $334,046.00 $299,754.50 $327,762.06 $0.00 $321,989.29

Total Pipe Price $11,374.37 $11,590.00 $11,214.85 $11,498.50 $12,047.50 $11,492.40 $10,675.00

Total Firm w/ 1/0 XLPE $319,131.57 $390,951.80

Total Esc w/ 1/0 XLPE $309,172.65 $375,012.06 $373,233.79

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TO:



Daryl Thompson – Vice Chair

Al Nadeau – Trustee

FROM:

Wade Lovelette – Technical Services

Superintendent



SUBJECT:

Otsego Substation Upgrade

BACKGROUND:

Back in the late fall of 2013 the Otsego substation experienced a fault in the relay protection at the main

substation transformer. GRE installed one of their relays as a temporary replacement. They are

recommending that we move the relay and related equipment into the metering building on site where it

will be out of the elements. Right now that equipment is housed in a cabinet outside next to the

transformer.

DISCUSSION:

This project came in costing more than expected and we will have to make adjustments to our projects for

this year in the electric budget.

ACTION REQUESTED:

Staff will ask the commission to approve adjusting the budget to allocate monies for this project.

67

Page 1 of 1


TO:





FROM:

Eric Volk – Water Superintendent



SUBJECT:

Well #2 Project Update

BACKGROUND:

The Well #2 project started the week before Christmas and was completed on March 13th

.

The project involved:

Pulling and reconditioning the well

Replacing old pipes

Sandblasting and painting the filter

Painting the floor

Replacing T-12 fluorescent lights with T-8 fluorescent lights

Replacement of all chemical lines and conduits

Installing a new VFD

DISCUSSION:

The well is almost ready to go back online. We’re just waiting for some water samples to come

back and then we’ll be able to start pumping again. I’ll be presenting a slide show of before and

after photos at the commission meeting.

ACTION REQUESTED:

There is no action requested.

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Page 1 of 2


TO:





FROM:

Troy Adams, P.E. – General Manager


AGENDA ITEM NUMBER: 6.1a

SUBJECT:

Staff Updates – General Manager

DISCUSSION:

This month in the history of Elk River Municipal Utilities: On March 7, 1948, the diesel

power plant located at the Elk River Dam went on line providing electricity to Elk River,

Zimmerman, Dayton, and the surrounding rural areas. #acenturyofservice

I have talked with American Public Power Association staff about the Spring Education

Conference. They had asked if I would be able to give a presentation on the Performance

Metrics and Incentive Compensation Policy that we’d developed in 2012. This

conference is in Colorado Springs early May. Due to scheduling conflicts, I’ve declined

their request to present at this conference but potentially I will give that presentation at

the APPA National Conference this June in Minneapolis, MN.

The MMPA Board of Directors met on February 24, 2015. It was reported that MMPA’s

2013 Integrated Resource Plan was approved by the Minnesota Public Utilities

Commission on January 29, 2015. The Board had a planning session focused on

renewable energy. The Board also discussed MMPA’s plans for natural-gas fired

distributed generation to meet the Agency’s future power supply needs.

On January 23, I chaired the MMUA Solar/DG Task Force meeting in Plymouth, MN.

Tom Sagstetter is also participating in the task force with me. The task force is working

to develop the municipal approach to solar. The areas of focus include: Education;

Development of model ordinance, interconnection agreement, and standard technical

requirements; Demonstration projects, project costs, and project production data; and

Rate design.

On Friday and Saturday March 13-14, I attended a Rotary President Elect Training in

Rochester, MN.

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Page 2 of 2

Interviews for the Billing Specialist position were held on Friday March 6. This position

was posted internally. The vacant Customer Service Specialist position created by filling

the Billing Specialist position will be posted and advertised this week.

An ad for the vacant Water Operator position was posted and sent to the League of

Minnesota Cities and The Elk River Star News. I hope to conduct interviews for this

position the week of April 7.

Mark Fuchs, Eric Volk, and I met with representatives from TKDA, a full-service

engineering, architectural, and planning firm headquartered in Saint Paul, MN. We

invited TKDA to ERMU to get a better understanding on the process for evaluating our

field services and administration facility needs as we do some long term planning.

My annual review is scheduled for the April Commission meeting. An online survey will

be used again to conduct the review. As in the past, this will be a 360° review with the

Commission, direct reporting managers, and the City Administrator participating in the

review process. If the Commission is interested in altering the review questions or

process, please provide suggestions or direction at the March Commission meeting.

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Page 1 of 1


TO:





FROM:

Theresa Slominski – Finance and Office Manager


AGENDA ITEM NUMBER: 6.1b

SUBJECT:

Staff Update

DISCUSSION:

Much of the time this month was spent working on the conversion and learning the new

software, as presented by the Customer Service Manager’s report. We continue to learn and

enjoy the improvements the software brings, and lament some of the losses. As a new “market”

for NISC, there are still some challenges for making a multiple service municipal utility work in

software designed for electric service co-op utilities. We are scheduling a meeting with the

management at NISC in Mandan to bring forth our concerns.

We also spent considerable time preparing for the audit. The auditors were here on Thursday

and Friday, February 26th

and February 27th

and all went well. There were some challenges for

them as they needed to familiarize themselves with our new software and the new reporting that

came with it, but we were able to work through it. They are at the City the week of March 9th

through March 13th

. The auditors hope to report to the commission at the April meeting, and are

tentatively scheduled for April 14th

.

Our most recent hire for the Purchasing Specialist did not work out, unfortunately, and we let her

go on Friday, March 6th

. We did not feel the next runner up candidates were the best fit and so

the position will be advertised again, this time in the Star Tribune, MMUA website, LMC

website, as well as posting on our website. We will be accepting applications through March

27th.

Michelle Anderson has been promoted from a Customer Service Representative (CSR) to the

Billing Specialist (a position that has been vacant since June 2014). She has been with us since

2008 and will be a welcome help with the new software. She will be fully transitioning to the

new position once a new CSR is hired. We will be advertising for a new CSR through the Star

News to replace her vacated position and will be accepting applications through March 20th

.

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Page 1 of 1


TO:





FROM:

Mark Fuchs – Electric Superintendent


AGENDA ITEM NUMBER: 6.1c

SUBJECT:

Staff Update

DISCUSSION:

Had four new services.

Continue working on collecting data with the GPS for our ArcView maps as time

permits.

Continue tree trimming.

Continue going thru the map book and inspecting equipment on the overhead and

underground system.

Continue working with the City of Elk River Streets Department trimming trees that are

in the road right-of-way.

The City shop does D.O.T.’s for our trucks and trailers. They will be doing these during

February, March and April.

Diversified completed annual inspections on the bucket and digger trucks. The

inspections include: Visual/Operational, Magnetic Particle, Dielectric, Load and Acoustic

Emission Testing.

Changed out the fluorescent lights to LED’s in the offices and break room at the Field

Services Building. We are also working on changing out the fixtures in the older shop to

LED’s.

The wind blew some garbage into our feeder located by the landfill. This caused the

recloser to operate and knock the generator off line.

A gopher or some other type of rodent chewed through an underground primary splice.

This caused one of the two feeders that feed a data center to open up resulting in us

having to feed them from a different feeder. We had Connexus come out to locate the

fault so we could thaw the ground and repair it.

72

Page 1 of 1


TO:



Al Nadeau – Vice-Chair

Daryl Thompson - Trustee

FROM:

Wade Lovelette – Superintendent of Technical

Services


AGENDA ITEM NUMBER: 6.1d

SUBJECT:

Staff Update

DISCUSSION:

The Locating department had a total of 120 locate tickets in February; four of them being

emergency tickets, two cancellations, three meets, 88 normal tickets, nine boundary surveys,

four non-excavation, and 10 updated tickets. When Richard Wagner is not locating he is

working on map book updates and the ArcView maps.

In February, the Security Systems Department had a total of 97 phone contacts, six systems

quoted, two system sales made, seven installs completed, 29 service calls and six personal

visits.

Electric Technicians continue with the meter reading, power bill, substation checks, hanging

red-tags, meter read-outs, dealing with meter and off-peak issues, and delivering and

installing new meters to commercial customers. They continue to change out the three phase

meters to radio read meters and help with the monthly engine runs. They are also re-

programming three-phase meters in the field for commercial and industrial loads. Jeff

Murray has been doing some infrared testing on distribution equipment. Jeff attended the

Upper Midwest Metering Association (UMMA) conference in Duluth; his education report

is attached.

The power plant staff did the monthly engine run on February 24th. Engines 1,2 and 4 ran

fine. Engine 3 was down as Wheeler World Inc. was working on the upgrade. They should

finish their work the week of March 9th

.

Staff continues to collect data with the GPS for our ArcView maps as time permits.

ATTACHMENTS:

Security Systems Weekly Update

Security Systems Analysis

Jeff Murray Education Report

73

13069 Orono Parkway

P.O. Box 430

Elk River, MN 55330-0430


Security System Weekly Update(sum of weeks) (total for calendar month)

Month of February-15 February-15

Number of Contacts 97 97

Number of systems quoted 6 6

Number of sales made 2 2

Number of Installs completed 7 7

Number of service calls 29 29

Personal Visits 6 6

Revenue Jan-15 31,014$

Expense Jan-15 14,894$

Margin* Jan-15 16,120$

YTD Revenue Jan-15 31,014$

YTD Expense Jan-15 14,894$

YTD Margin* Jan-15 16,120$

* Margin calculations exclude depreciation, payroll taxes, benefits coverage and office support

74

Security Revenue and Margin 2014

Jan Feb Mar April May June July August Sept Oct Nov Dec

Total Year

Budget

Revenue 29,110 28,705 20,044 20,946 23,326 24,542 21,080 23,547 23,042 24,069 21,502 22,690 **

YTD Revenue 29,110 57,815 77,859 98,805 122,131 146,674 167,754 191,301 214,343 238,412 259,914 282,604 265,000

Expense 12,292 13,237 20,940 16,508 16,354 14,136 21,308 16,670 12,898 21,556 15,469 16,761 **

YTD Expense 12,292 25,529 46,469 62,977 79,331 93,467 114,775 131,445 144,342 165,898 181,367 198,128 215,000

Margin* 16,818 15,468 -896 4,438 6,972 10,407 -228 6,877 10,145 2,513 6,033 5,929

YTD Margin* 16,818 32,286 31,391 35,829 42,801 53,207 52,979 59,856 70,001 72,514 78,547 84,476 50,000

** April 2014 results exclude correction for 40K overbilling on security services.


Security Revenue and Margin 2015

Jan Feb Mar April May June July August Sept Oct Nov Dec

Total Year

Budget

Revenue 31014

YTD Revenue 31,014 31,014 31,014 31,014 31,014 31,014 31,014 31,014 31,014 31,014 31,014 31,014 270,000

Expense 14894

YTD Expense 14,894 14,894 14,894 14,894 14,894 14,894 14,894 14,894 14,894 14,894 14,894 14,894 215,000

Margin* 16,120 0 0 0 0 0 0 0 0 0 0 0

YTD Margin* 16,120 16,120 16,120 16,120 16,120 16,120 16,120 16,120 16,120 16,120 16,120 16,120 55,000


75

-$50,000

$0

$50,000

$100,000

$150,000

$200,000

$250,000

$300,000

$350,000

2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014

Security Contribution in Dollars

Revenue Expense Margin

76

77

Page 1 of 2


TO:





FROM:

Eric Volk - Water Superintendent


AGENDA ITEM NUMBER: 6.1e

SUBJECT:

Staff Update

DISCUSSION:

Delivered 6 new residential water meters.

Sealed the water meter and took curb stop ties from 7 water services.

Went on 7 Service calls.

Completed 25 BACTI/Total Chlorine Residual Samples; all confirmed negative for

Coliform Bacteria.

Completed 20 routine fluoride samples. All samples met MDH standards.

Annual well maintenance is almost over for the winter. We have two filters left to clean

and recharge before the busy season. The operators have done an outstanding job getting

the wells and filters ready for summer. The annual preventive maintenance involves

recharging and cleaning the filters, replacing chemical lines, changing oil in compressors,

and painting. The operators use their experience to try to anticipate any problems that

may come up in the summer. In order to prevent such problems they will replace items

that are known to fail.

I have started working with Badger State Inspections on painting the inside of Gary Street

Water Tower. The belly of the tank, dry tube, and condensate ceiling will be sandblasted

and painted this summer.

Sprint has started the 2.5 upgrades on all three water towers. The projects will only take a

couple weeks.

With help of Russ Stuhr, Mike Langer installed a new water meter in Well #8. This was

not an easy task as it involved a 12” pipe. A filler flange had to be ordered and installed

as well.

We’ve been working with Bolton and Menk to complete the annual updates for our

mapping system. We will be printing map books shortly and will continually update the

maps.

We are preparing to begin locating and exercising the gate valves that are located within

the 2015 street project areas. After the project is complete, we’ll go and locate each valve

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Page 2 of 2

to ensure it is visible. We’ll also be checking the valve boxes to make sure they are not

filled in with dirt or asphalt.

ATTACHMENTS:

February Pumping By Well

79

Values Are Displayed in Millions of Gallons (Well #, Gallons Pumped, Percentage of Pumping)

Well #2, 0, 0%

Well #3, 16.804, 37%

Well #4, 8.607, 19%

Well #5, 10.889, 24%

Well #6, 3.621, 8%

Well #7, 0, 0%

Well #8, 2.622, 6%

Well #9, 2.65, 6%

February 2014 Monthly Pumping By Well

80

Page 1 of 2


TO:





FROM:

Tom Sagstetter - Conservation and Key Accounts

Manager

MEETING DATE: March 17

th, 2015

AGENDA ITEM NUMBER:

6.1f

SUBJECT:

Staff Update

DISCUSSION:

Attended the Clean Energy Research Teams Conference in St. Cloud. The theme this

year was Community-Driven Clean Energy. Many of the educational sessions focused

on Solar PV generation sites and financing of those facilities. The focus has turned from

small individual owner sites on the owner’s property, to third party owned large

generation sites. There were also discussions on the challenges of getting installations

approved by local governmental units through building permits and set-back

requirements. There is a major push in the solar industry to get as many installations

booked as the investment tax credits will be eliminated in 2017, unless the Federal

Government extends those incentives.

The landfill gas plant had a very good year in electric production, and a relatively low

year in operational costs. The landfill gas plant maintained a delivered capacity factor of

99% which resulted in over 26 million kWh being delivered to the market. That is

enough energy to supply approximately 2,600 average residential homes for one year. As

a result of the high capacity factor, Waste Management received a bonus check of

$21,336.40 for plant operations in 2014. Sherburne County received a bonus payment of

$20,000 for 2014. Please see attached letters for more details.

Conservation rebates are going well and ERMU has started using the new Energy

Savings Platform to document energy savings and spending for the conservation

improvement programs (CIP). The new platform was developed by a third party for the

Minnesota Division of Energy Resources.

Energy City tours continue to be popular. Jackson Middle School toured the facility and

there were approximately 35 students in 6th

grade. Kristin is scheduling many tours as

we head into spring and peak season for the school field trips.

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Page 2 of 2

Worked with staff and customers during unplanned outages that were caused by very

large rodents and flying trash.

There has been a fairly large volume of calls regarding high bills. February was cold and

the new bill presentation has some customers calling in to ask questions about what

changed on their bills.

ATTACHMENTS:

Letter to Waste Management – LFG to Electric Generation Facility Performance for 2014

Letter to Sherburne County – LFG to Electric Generation Facility Performance for 2014

82

83

84

Documents

ELK RIVER MUNICIPAL UTILITIES96bda424cfcc34d9dd1a-0a7f10f87519dba22d2dbc6233a731e5.r41.cf2.rackcdn.…SPECIAL MEETING OF THE UTILITIES COMMISSION March 17, 2015, 3:30 P.M. Utilities