08-27-2025 HUCCPHUTCHINSON UTILITIES COMMISSION
AGENDA
REGULAR MEETING
August 27, 2025
3:00 p.m.
1. CONFLICT OF INTEREST
2. APPROVE CONSENT AGENDA
a. Approve Minutes
b. Ratify Payment of Bills
3. APPROVE FINANCIAL STATEMENTS
4. OPEN FORUM
5. COMMUNICATION
a. City Administrator
b. Divisions
C. Human Resources
d. Legal
e. General Manager
6. POLICIES
a. Review Policies
i.
Hutchinson Utilities Commission
ii.
Establishing a New Electric/Natural Gas Account
iii.
Deposit Requirement — Residential
iv.
Deposit Requirement — Commercial/Industrial
v.
Terminating Electric/Natural Gas Service by Customer
vi.
Definition of Your Bill
vii.
Errors in Billing
viii.
Payment of Your Bill
ix.
Automatic Bill Payment Plan
x.
Budget Payment Plan
xi.
Explanation of Billing Procedure
xii.
Disconnection of Residential Services by HUC
xiii.
Disconnection of Commercial Services by HUC
xiv.
After Hours Reconnection Policy
xv.
Landlord Acknowledgment
xvi.
Inserts with Utility Bills
xvii.
Identity Theft — "Red Flag Program"
xviii.
Minnesota Cold Weather Rule
xix.
Minnesota Government Data Practices Act and Public Records
Request
b. Approve Changes
7. UNFINISHED BUSINESS
8. NEW BUSINESS
Approve Req#10337 — Plant #1 Substation Circuit Breakers
9. ADJOURN
MINUTES
Regular Meeting — Hutchinson Utilities Commission
Wednesday, July 30, 2025
Call to order — 3:00 p.m.
President Matt Cheney called the meeting to order. Members present: President Matt
Cheney; Secretary Don Martinez; Vice President Troy Pullis; Commissioner Kathy
Silvernale; Commissioner Tom Lambert; GM Jeremy Carter; Attorney Marc Sebora:
1. Conflict of Interest
2. Approve Consent Agenda
a. Approve Minutes
b. Ratify Payment of Bills
Motion by Commissioner Martinez second by Commissioner Lambert to Approve
the Consent Agenda. Motion carried unanimously.
3. Approve Financial Statements
Mr. Martig presented the Financial Statements. Electric Division net profit increased
by $166k over June of last year. Sales for Resale were up $893k due to a large
increase in generation sales into the market. With the amount of generation running,
there was an increase of $258k in generator fuels and chemicals and an increase in
some additional operating expenses. Natural Gas Division was similar to last year.
GM Carter noted operating expense increase also included expenses from the HTI
substation repair along with Rata testing that was completed. GM Carter reviewed
market sales for the month and stated that $328k was added to the rate stabilization
fund. Natural Gas Division trending well. GM Carter reviewed the Investments and
money market.
Motion by Commissioner Silvernale, second by Commissioner Pullis to Approve the
Financial Statements. Motion carried unanimously.
4. Open Forum
5. Communication
a. City Administrator —Matthew Jaunich —Absent
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i. Dan Lang, Engineering Services Manager —
1. Running generation
2. Hutch Sub project
ii. Dave Hunstad, Electric Transmission/Distribution Manager — Nothing to
report
iii. Mike Gabrielson, Production Manager —Absent
iv. Jared Martig, Financial Manager — Nothing to Report
v. Byron Bettenhausen, Natural Gas Manager —
1. New Installs
2. Working on policy change listed below
c. Human Resources — Angie Radke -
i. Reviewing Policies
ii. Catching up on miscellanies tasks
iii. Starting to work on Record Retention
d. Legal — Marc Sebora —
i. Nothing to report
e. General Manager — Jeremy Carter
i. Prepaid Deal review
ii. Received Energy Data Center contract back, need to review
iii. Meeting with New Ulm on August 27
iv. Working on Union Contract regarding PFML
v. Ms. Radke is working on receiving quotes from a 3rd party regarding PFML
6. Policies
a. Review Policies
i. Appendices of Exempt Handbook
ii. Appendices of Non -Exempt Handbook
No changes recommended at this time
b. Approve Changes
i. Natural Gas Service Requirements and Changes
Mr. Bettenhausen spoke of the policy change to Natural Gas Service
Requirements and Changes. Staff has costed through the detail for Residential,
Commercial and Industrial new service installs and compared to other peers.
Staff recommends the proposed fees along with adding verbiage about relocation
of the natural gas service line.
Motion by Commissioner Martinez, second by Commissioner Lambert to Approve
Policy Changes. Motion carried unanimously.
7. Unfinished Business
8. New Business
a. Re -adopt the Data Practice Act & Public Records Request Policy
Mr. Sebora presented Re -adopt the Data Practices Act & Public Records Request
Policy. The State of Minnesota requires that political subdivisions like HUC adopt a
data practices policy, which guides both the HUC and members of the public in
2
obtaining information from HUC. State of Minnesota also requires that HUC adopt
the data practices policy annually prior to August 1. There are no changes.
Motion by Commissioner Silvernale, second by Commissioner Pullis to Approve
Data Practice Act. Motion carried unanimously.
b. Approve Hutchinson Substation — Circuit Breaker Change Order #2
Mr. Lang presented Approval of Hutchinson Substation Circuit Breaker Change
Order #2. The change order issued to Border States is to approve a price change
due to import tariffs on the circuit breakers for the Hutchinson Substation project.
Motion by Commissioner Pullis, second by Commissioner Lambert to Approve
Hutchinson Substation Circuit Breaker Change Order #2. Motion carried unanimously.
c. — Approve Req#010174 — Electric Meter Testing Equipment
Mr. Hunstad presented Approval of Req#010174 Electric Meter Testing Equipment.
The meter testing equipment HUC has today is from 1992 and is no longer supported
or compatible with the current software. Several different manufactures were looked
at and Probewell has the best options for mobile applications.
Motion by Commissioner Silvernale, second by Commissioner Pullis to Approve
Req#010174 Electric Meter Testing Equipment. Motion carried unanimously.
d. —Approve Willmar-HUC Line Multi -Party Joint Coordination Agreement
Mr. Lang presented Approval of Willmar-HUC Line Multi -Party Joint Coordination
Agreement. The Agreement is between Great River Energy, Southern Minnesota
Municipal Power Agency and Hutchinson Utilities Commission that defines the project
scope, including the roles and responsibilities and commitment of each party for the
69kV Willmar Line rebuild throughout design, permitting and construction.
Motion by Commissioner Martinez, second by Commissioner Silvernale to Approve
Willmar-HUC Line Multi -Party Joint Coordination Agreement. Motion carried
unanimously.
e. — Approve Req#010324 - Crow River Crossing Project
Mr. Bettenhausen presented Approval of Req#010324 Crow River Crossing Project.
Two quotes were received to directional bore approximately 1700' of 6" and 8" HDPE
under the South Fork of the Crow River. The work will start at W Hwy 7 Services Road,
extend to the South and end on the South side of the Crow River.
Discussion was held on the path taken and the easements and permits that are
needed.
3
Motion by Commissioner Lambert, second by Commissioner Pullis to Approve
Req#010324 Crow River Crossing Project. Motion carried unanimously.
f. —Approve Req#010325 - Removal of District Regulating Station #3
Mr. Bettenhausen presented Approval of Req#010325 Removal of District Regulating
Station #3. DRS#3 has an underground valve that leaks and needs to be removed and
replaced. HUC has had the regulating station closed and out of service for over 9
months and has been monitoring the pressure. There has been less than 1 lb of change
in the header pressure, Staff is recommending to remove the DRS.
Motion by Commissioner Pullis, second by Commissioner Lambert to Approve
Req#010325 Removal of District Regulating Station #3. Motion carried unanimously.
9. Adjourn
There being no further business, a motion by Commissioner Pullis, second by
Commissioner Silvernale to adjourn the meeting at 3:33pm. Motion carried
unanimously.
ATTEST:
Matt Cheney, President
12
Don Martinez, Secretary
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HUTCHINSON UTILITIES COMMISSION
COMBINED DIVISIONS
FINANCIAL REPORT FOR JULY, 2025
Combined Division
Customer Revenue
Sales for Resale
NG Transportation
Electric Division Transfer
Other Revenues
Interest Income
TOTAL REVENUES
Salaries & Benefits
Purchased Commodities
Transmission
Generator Fuel/Chem.
Depreciation
Transfers (Elect./City)
Operating Expense
Debt Interest
TOTAL EXPENSES
NET PROFIT/(LOSS)
58.3% of Year Comp.
2025 2024 Di . %Chna 2025 2024 Di %Chna Full Yr Bud %of Bud
$ 2,922,751 $ 2,961,062 $ (38,311)
$ 1,155,506 $ 280,346 $ 875,160
$ 171,496 $ 174,698 $ (3,202)
$ 60,639 $ 60,383 $ 255
$ 48,671 $ 64,128 $ (15,457)
$ 72,529 $ 79,418 $ (6,889)
$ 4,431,591 $ 3,620,035 $ 811,556
$ 668,585 $ 707,190 $ (38,605)
$ 1,556,126 $ 1,590,885 $ (34,758)
$ 211,645 $ 276,627 $ (64,982)
$ 591,888 $ 179,093 $ 412,795
$ 345,908 $ 364,186 $ (18,278)
$ 222,524 $ 222,269 $ 255
$ 297,532 $ 306,126 $ (8,593)
$ 49,688 $ 58,538 $ (8,850)
$ 3,943,897 $ 3,704,914 $ 238,984
$ 487,694 $ (84,879) $ 572,573
(1.3%)
$ 21,384,063
$ 20,723,530
$ 660,532
3.2%
$ 38,041,145
56.2%
312.2%
$ 4,229,626
$
2,030,702
$ 2,198,924
108.3%
$ 3,490,250
121.2%
(1.8%)
$ 1,203,909
$
1,108,664
$ 95,245
8.6%
$ 2,071,218
58.1%
0.4%
$ 424,472
$
422,683
$ 1,789
0.4%
$ 727,666
58.3%
(24.1%)
$ 357,173
$
1,084,722
$ (727,549)
(67.1%)
$ 483,841
73.8%
(8.7%)
$ 442,617
$
595,973
$ (153,356)
(25.7%)
$ 633,457
69.9%
22.4%
$ 28,041,860
$ 25,966,275
$ 2,075,585
8.0%
$ 45,447,577
61.7%
(5.46%) $ 4,591,197 $ 4,641,769 $ (50,572)
(2.2%) $ 11,971,771 $ 11,542,952 $ 428,820
(23.5%) $ 1,530,862 $ 1,467,565 $ 63,297
230.5% $ 1,376,772 $ 738,232 $ 638,541
(5.0%) $ 2,441,136 $ 2,552,008 $ (110,872)
0.1% $ 1,557,670 $ 1,555,883 $ 1,787
(2.8%) $ 2,175,540 $ 1,913,228 $ 262,311
(15.1%) $ 347,816 $ 409,766 $ (61,950)
6.5% $ 25,992,766 $ 24,821,403 $ 1,171,363
(674.6%) $ 2,049,095 $ 1,144,872 $ 904,222
July
July
i,
YTD
YTD
2025
2024
Change
2025
2024
Change
Gross Margin %:
34.8%
27.6%
7.2%
34.6%
32.1%
2.5%
Operating Income Per Revenue $ (%):
10.0%
-4.4%
14.5%
6.3%
0.0%
6.4%
Net Income Per Revenue $ (%):
11.0%
-2.3%
13.3%
7.3%
4.4%
2.9%
(1.1%)
$ 8,248,534
55.7%
3.7%
$ 20,256,167
59.1%
4.3%
$ 3,015,064
50.8%
86.5%
$ 1,284,200
107.2%
(4.3%)
$ 4,310,000
56.6%
0.1%
$ 2,670,292
58.3%
13.7%
$ 3,174,901
68.5%
i5.1%
$ 596,257
58.3%
4.7%
$ 43,555,415
59.7%
$ 1,892,162 108.3%
2025
HUC
Budget
Target
34.2%
3.5%N
4.2%N
uuIIUuIINNI
HUTCHINSON UTILITIES COMMISSION
ELECTRIC DIVISION
FINANCIAL REPORT FOR JULY, 2025
2025
2024
Di .
Electric Division
Customer Revenue
$
2,410,518
$ 2,444,189
$
(33,671)
Sales for Resale
$
1,155,506
$ 280,346
$
875,160
Other Revenues
$
13,967
$ 13,820
$
147
Interest Income
$
37,659
$ 41,103
$
(3,444)
TOTAL REVENUES
$
3,617,650
$ 2,779,458
$
838,192
Salaries & Benefits $ 494,178 $ 506,737 $ (12,559)
Purchased Power $ 1,300,680 $ 1,301,029 $ (349)
Transmission $ 211,645 $ 276,627 $ (64,982)
Generator Fuel/Chem. $ 591,888 $ 179,093 $ 412,795
Depreciation $ 248,293 $ 270,975 $ (22,683)
Transfers (Elect./City) $ 172,789 $ 172,534 $ 255
Operating Expense $ 174,293 $ 225,257 $ (50,964)
Debt Interest $ 32,771 $ 35,305 $ (2,533)
TOTAL EXPENSES $ 3,226,538 $ 2,967,557 $ 258,982
NET PROFIT/(LOSS) $ 391,112 $ (188,099) $ 579,211
58.3% of Year Comp.
%Chna
2025
2024
Di
%Chna
FullYrBud
%of Bud
(1.4%)
$ 14,182,024
$ 13,780,125
$ 401,899
2.9%
$ 25,609,217
55.4%
312.2%
$ 4,229,626
$ 2,030,702
$ 2,198,924
108.3%
$ 3,490,250
121.2%
1.1%
$ 160,530
$ 127,837
$ 32,693
25.6%
$ 191,126
84.0%
(8.4%)
$ 236,040
$ 307,745
$ (71,705)
(23.3%)
$ 333,457
70.8%
30.2%
$ 18,808,220
$ 16,246,410
$ 2,561,811
15.8%
$ 29,624,050
63.5%
(2.5%) $ 3,456,585 $ 3,433,055 $ 23,530
(0.0%) $ 7,399,796 $ 6,975,652 $ 424,144
(23.5%) $ 1,530,862 $ 1,467,565 $ 63,297
230.5% $ 1,376,772 $ 738,232 $ 638,541
(8.4%) $ 1,756,796 $ 1,900,428 $ (143,631)
0.1% $ 1,209,523 $ 1,207,735 $ 1,788
(22.6%) $ 1,469,580 $ 1,276,655 $ 192,925
(7.2%) $ 229,400 $ 247,133 $ (17,733)
8.7% $ 18,429,315 $ 17,246,454 $ 1,182,861
307.9%) $ 378,906 $ (1,000,044) $ 1,378,950
0.7%
$ 5,955,489
58.0%
6.1%
$ 12,605,893
58.7%
4.3%
$ 3,015,064
50.8%
86.5%
$ 1,284,200
107.2%
(7.6%)
$ 3,200,000
54.9%
0.1%
$ 2,073,468
58.3%
15.1%
$ 2,145,148
68.5%
7.2%
$ 393,257
58.3%
6.9%
$ 30,672,519
60.1%
137.9%)
$ (1,048,469)
(36.1%)
58.3%ofYear Comp.
2025
2024
Di .
%Chna
2025
2024
Di
%Chna
FullYrBud
%of Bud
Electric Division
Residential
6,461,171
5,518,207
942,964
17.09%
31,802,335
29,831,432
1,970,903
6.61%
54,084,350
58.8%
All Electric
184,217
146,665
37,552
25.60%
1,532,358
1,330,683
201,675
15.16%
2,585,300
59.3%
Small General
1,810,855
1,526,582
284,273
18.62%
10,558,006
9,873,959
684,047
6.93%
18,348,996
57.5%
Large General
9,815,630
7,134,530
2,681,100
37.58%
52,301,880
43,941,003
8,360,877
19.03%
83,540,973
62.6%
Industrial
8,962,000
10,518,000
(1,556,000)
(14.79%)
57,995,000
64,274,000
(6,279,000)
(9.77%)
113,841,379
50.9%
Total KWH Sold
27,233,873
24,843,984
2,389,889
9.62%
154,189,579
149,251,077
4,938,502
3.31%1
272,400,998
56.6%
July
July
YTD
YTD
2025
HUC
2025
2024
Change
2025
2024
Change
Budget
Target
Gross Margin %:
30.0%
19.8%
10.2%
29.2%
25.7%
3.4%
27.0%
Operating Income Per Revenue $ (%):
10.8%
-7.2%
18.0%
1.7%
-6.9%
8.6%
-3.5%
Net Income Per Revenue $ (%):
10.8%
-6.8%
17.6%
2.0%
-6.2%
8.2%
-3.5%
Customer Revenue per KWH:
$0.0885
$0.0984
-$0.0099
$0.0920
$0.0923
-$0.0004
$0.0940
Total Power Supply Exp. per KWH:
$0.0920
$0.0883
$0.0037
$0.0850
$0.0791
$0.0059
$0.0784
$0.0784
Net Profit increased by $579,211 over July 2024. Usage was up 9.62% but there was a slight decrease in Customer Revenue due to the PCA bringing in an additional
$276,079 in July 2024. Sales for Resale were up $875,160 due to a large increase in generation sales into the market. This generation is also the reason for the
$412,795 increase in generator fuels and chemicals.
Sales for Resale of $1,155,506 consisted of $924,506 in market sales, $98,000 in capacity sales to Rice Lake, $70,000 in capacity sales to AEP, and $63,000 in
capacity sales to Nextera. July 2024 Sales for Resale of $280,346 included $74,121 in market sales, $98,000 in capacity sales to Rice Lake and $108,225 in capacity
sales to AEP. July 2023 Sales for Resale of $468,395 consisted of $224,145 in market sales, $98,000 in capacity sales to Rice Lake and $146,250 in capacity sales to AEP
Overall Purchased Power decreased by $349. MRES purchases increased by $42,645 and market purchases/MISO costs decreased by $42,994.
The average cost of MISO power was $35.22/mwh (1,895 mwh's purchased), compared to $24.29/mwh (3,239 mwh's purchased) in July 2024.
There was no Power Cost Adjustment for July 2025 leaving the total at $151,798 YTD. In July, $274,373 was added to the rate stabilization fund, which is now above
the $1.2M ceiling threshold.
Power Cost Adjustment for July 2024 was $.01113/kwhr bringing in an additional $276,079 for the month and $425,066 YTD.
HUTCHINSON UTILITIES COMMISSION
GAS DIVISION
FINANCIAL REPORT FOR JULY, 2025
583% of Year Comp.
2025
2024
2
%Chna
2025
2024
2 .
%Chna
Full Yr Bud
% of Bud
Gas Division
Customer Revenue
$
512,233
$ 516,873
$
(4,641)
(0.9%)
$
7,202,039
$
6,943,405
$
258,634
3.7%
$ 12,431,928
57.9%
Transportation
$
171,496
$ 174,698
$
(3,202)
(1.8%)
$
1,203,909
$
1,108,664
$
95,245
8.6%
$ 2,071,218
58.1%
Electric Div. Transfer
$
60,639
$ 60,383
$
255
0.4%
$
424,472
$
422,683
$
1,789
0.4%
$ 727,666
58.3%
Other Revenues
$
34,704
$ 50,308
$
(15,604)
(31.0%)
$
196,643
$
956,885
$
(760,242)
(79.4%)
$ 292,715
67.2%
Interest Income
$
34,871
$ 38,315
$
(3,444)
(9.0%)
$
206,578
$
288,228
$
(81,650)
(28.3%)
$ 300,000
68.9%
TOTAL REVENUES
$
813,941
$ 840,577
$
(26,636)
(3.2%)
$
9,233,640
$
9,719,865
$
(486,225)
(5.0%)
$ 15,823,527
58.4%
Salaries & Benefits
$
174,407
$ 200,453
$
(26,047)
(13.0%)
$
1,134,612
$
1,208,714
$
(74,102)
(6.1%)
$ 2,293,045
49.5%
Purchased Gas
$
255,446
$ 289,855
$
(34,410)
(11.9%)
$
4,571,975
$
4,567,300
$
4,676
0.1%
$ 7,650,274
59.8%
Operating Expense
$
123,239
$ 80,868
$
42,371
52.4%
$
705,959
$
636,573
$
69,386
10.9%
$ 1,029,753
68.6%
Depreciation
$
97,616
$ 93,211
$
4,405
4.7%
$
684,340
$
651,580
$
32,760
5.0%
$ 1,110,000
61.7%
Transfers (City)
$
49,735
$ 49,735
$
(0)
(0.0%)
$
348,147
$
348,148
$
(1)
(0.0%)
$ 596,824
58.3%
Debt Interest
$
16,917
$ 23,233
$
(6,317)
0.0%
$
118,417
$
162,633
$
(44,217)
27.2%
$ 203,000
58.3%
TOTAL EXPENSES
$
717,359
$ 737,357
$
(19,998)
(2.7%)
$
7,563,451
$
7,574,949
$
(11,498)
(0.2%)
$ 12,882,896
58.7%
NET PROFIT/(LOSS)
$
96,582
$ 103,220
$
(6,638)
(6.4%)l
$ 2,940,631
56.8%
1,670,189 $ 2,144,916 $ (474,727) (22.1%)
2025 2024 2 %Chnq 2025 2024 p %Chnq Full Yr Bud % of Bud
Gas Division
Residential
6,161,407
5,792,635
368,772
6.37%
266,269,258
227,070,945
39,198,313
17.26%
435,250,000
61.2%
Commercial
7,467,182
7,867,371
(400,189)
(5.09%)
199,403,071
169,876,647
29,526,424
17.38%
337,584,000
59.1%
Industrial
48,314,392
46,233,294
2,081,098
4.50%
500,183,764
459,327,704
40,856,060
8.89%
895,764,000
55.8%
Total CF Sold
61,942,981
59,893,300
2,049,681
3.42%
965,856,093
856,275,296
109,580,797
12.80%
1,668,598,000
57.9%
July
July
YTD
YTD
2025
2025
2024
Change
2025
2024
Change
Budget
Gross Margin %:
57.8%
55.9%
1.9%
45.8%
43.9%
1.9%
48.0%
Operating Income Per Revenue $ (%):
6.5%
5.5%
0.9%
16.0%
12.8%
3.2%
17.0%
Net Income Per Revenue $ (%):
11.9%
12.3%
-0.4%
18.1%
22.1%
-4.0%
18.6%
Contracted Customer Rev. per CF:
$0.0065
$0.0058
$0.0007
$0.0067
$0.0069
-$0.0002
$0.0061
Customer Revenue per CF:
$0.0127
$0.0154
-$0.0027
$0.0082
$0.0095
-$0.0012
$0.0087
Total N.G. Supply Exp. per CF:
$0.0051
$0.0056
($0.0005)
$0.0050
$0.0056
($0.0006)
$0.0048
HUC
Target
$0.0087
$0.0048
Notes/Graphs:
July Net Income decreased by $6,638. Usage was up 3.42%, but revenue decreased by $4,641 because of a large fuel cost credit provided back to customers that was
not provided in July of 2024.
July 2025 Fuel Credit Adjustment was $3.1828/MCF crediting customers $57,719 for the month and $596,051 YTD.
There was no Fuel Cost Adjustment for July 2024 but $150,146 was returned to customers YTD.
Current Assets
UnrestrictedlUndesignated Cash
Cash
Petty Cash
Designated Cash
Capital Expenditures - Five Yr. CIP
Payment in Lieu of Taxes
Rate Stabilization - Electric
Rate Stabilization - Gas
Catastrophic Funds
Restricted Cash
Bond & Interest Payment 2017
Bond & Interest Payment 2012
Debt Service Reserve Funds
Total Current Assets
Receivables
Accounts (net of uncollectible allowances)
Interest
Total Receivables
Other Assets
Inventory
Prepaid Expenses
Sales Tax Receivable
Deferred Outflows - Electric
Deferred Outflows - Gas
Total Other Assets
Total Current Assets
Capital Assets
Land & Land Rights
Depreciable Capital Assets
Accumulated Depreciation
Construction - Work in Progress
Total Net Capital Assets
HUTCHINSON UTILITIES COMMISSION
BALANCE SHEET - CONSOLIDATED
JULY 31, 2025
Electric Gas Total
Division Division 2025
(2,841,201.29) 14,353,923.48 11,512,722.19
680.00 170.00 850.00
2,750,000.00 700,000.00 3,450,000.00
1,345,802.00 596,824.00 1,942,626.00
1,443,969.35 - 1,443,969.35
- 615,294.19 615,294.19
800,000.00 200,000.00 1,000,000.00
Total Net Change
2024 Total (YTD)
14,424,158.22 (2,911,436.03)
850.00 -
3,450,000.00 -
1,942,626.00 -
398, 808.13 1,045,161.22
615,294.19 -
1,000,000.00 -
592,609.37
-
592,609.37
789,104.16
(196,494.79)
-
1,353,833.32
1,353,833.32
1,449,200.00
(95,366.68)
1,183,256.00
2,072,000.00
3,255,256.00
3,255,656.00
(400.00)
5,275,115.43
19,892,044.99
25,167,160.42
27,325,696.70
(2,158,536.28)
2,466,095.66
519,127.69
2,985,223.35
2,898,925.73
86,297.62
74,314.28
74,314.29
148,628.57
141,412.63
7,215.94
2,540,409.94
593,441.98
3,133,851.92
3,040,338.36
93,513.56
2,052,221.75
528,517.72
2,580,739.47
2,615,056.55
(34,317.08)
734,176.85
87,913.59
822,090.44
383,633.86
438,456.58
447,658.73
-
447,658.73
375,045.32
72,613.41
342,759.00
-
342,759.00
741,556.00
(398,797.00)
-
114,253.00
114,253.00
247,185.00
(132,932.00)
3,576,816.33
730,684.31
4,307,500.64
4,362,476.73
(54,976.09)
11,392,341.70 21,216,171.28
690,368.40
3,899,918.60
94,055,600.33
44,579,509.55
(49,986,874.56)
(22,937,441.54)
4,729,277.79
143,111.04
49,488,371.96 25,685,097.65
32,608,512.98 34,728,511.79 (2,119,998.81)
4,590,287.00
4,590,287.00
-
138,635,109.88
158,003,077.60
(19,367,967.72)
(72,924,316.10)
(94,199,745.38)
21,275,429.28
4,872,388.83
3,743,179.51
1,129,209.32
75,173,469.61
72,136,798.73
3,036,670.88
Total Assets 60,880,713.66 46,901,268.93 107,781,982.59 106,865,310.52 916,672.07
HUTCHINSON UTILITIES COMMISSION
BALANCE SHEET - CONSOLIDATED
JULY 31, 2025
Electric
Gas
Total
Total
Net Change
Division
Division
2025
2024
Total (YTD)
Current Liabilities
Current Portion of Long-term Debt
Bonds Payable
790,000.00
1,980,000.00
2,770,000.00
2,655,000.00
115,000.00
Bond Premium
-
185,608.32
185,608.32
185,608.32
-
Lease Liability - Solar Array
19,546.00
-
19,546.00
-
19,546.00
Accounts Payable
3,278,588.60
430,777.68
3,709,366.28
2,485,230.71
1,224,135.57
Accrued Expenses
Accrued Interest
65,542.72
33,833.34
99,376.06
117,076.04
(17,699.98)
Accrued Payroll
47,881.60
17,636.26
65,517.86
213,160.50
(147,642.64)
Total Current Liabilities
4,201,558.92
2,647,855.60
6,849,414.52
5,656,075.57
1,193,338.95
Long -Term Liabilities
Noncurrent Portion of Long-term Debt
2017 Bonds
11,750,000.00
-
11,750,000.00
12,540,000.00
(790,000.00)
2012 Bonds
-
2,080,000.00
2,080,000.00
4,060,000.00
(1,980,000.00)
Bond Premium 2012
412,635.84
61,869.07
474,504.91
693,570.19
(219,065.28)
Pension Liability- Electric
1,832,248.00
-
1,832,248.00
2,776,372.00
(944,124.00)
Pension Liability - Electric OPEB
39,880.00
-
39,880.00
64,096.00
(24,216.00)
Pension Liability- Nat Gas
-
610,749.00
610,749.00
925,458.00
(314,709.00)
Pension Liability - Nat Gas OPEB
-
13,293.00
13,293.00
21,365.00
(8,072.00)
Accrued Vacation Payable
569,807.22
169,522.80
739,330.02
718,594.32
20,735.70
Accrued Severance
208,347.54
37,374.19
245,721.73
153,920.05
91,801.68
Deferred Outflows - Electric
1,294,449.00
-
1,294,449.00
998,815.00
295,634.00
Deferred Outflows - Nat Gas
-
431,483.00
431,483.00
332,938.00
98,545.00
Total Long -Term Liabilities
16,107,367.60
3,404,291.06
19,511,658.66
23,285,128.56
(3,773,469.90)
Net Position
Retained Earnings
40,571,787.14
40,849,122.27
81,420,909.41
77,924,106.39
3,496,803.02
Total Net Position
40,571,787.14
40,849,122.27
81,420,909.41
77,924,106.39
3,496,803.02
Total Liabilities and Net Position 60,880,713.66 46,901,268.93 107,781,982.59 106,865,310.52 916,672.07
Hutchinson Utilities Commission
Cash -Designations Report, Combined
7/31/2025
Financial
Institution
Current Interest Rate
Annual
Interest
Balance,
July 2025
Balance,
June 2025
Change in
Cash/Reserve
Position
Savings, Checking, Investments varies varies varies 25,167,160.42 26,059,835.43 (892,675.01)
Total Operating Funds 25,167,160.42 26,059,835.43 (892,675.01)
Debt Reserve Requirements Bond Covenants - sinking fund
Debt Reserve Requirements Bond Covenants -1 year Max. P & I
Total Restricted Funds
Operating Reserve
Rate Stabalization Funds
PILOT Funds
Catastrophic Funds
Capital Reserves
Total Designated Funds
Min 60 days of 2025 Operating Bud.
Charter (Formula Only)
Risk Mitigation Amount
5 Year CIP (2025-2029 Fleet & Infrastructure Maintenance)
1,946,442.69 1,665,921.33 280,521.36
3,255,256.00 3,255,256.00 -
5,201,698.69 4,921,177.33 280,521.36
6,542,569.17
6,542,569.17 -
2,059,263.54
1,784,890.12 274,373.42
1,942,626.00
1,942,626.00 -
1, 000, 000.00
1, 000, 000.00
3,450,000.00
3,450,000.00 -
14,994,458.71
14,720,085.29 274,373.42
YE
YE
YE
YE
YTD
HUC
2021
2022
2023
2024
2025
Target
Debt to Asset 30.8%
31.4%
28.6%
26.0%
24.5%
Current Ratio 5.22
4.47
4.48
3.67
3.95
RONA 0.41%
-1.38%
1.96%
2.63%
2.15%
Change in
Cash Balance (From 12131114 to
713112025)
Month End
Electric
Elec. Change
Natural Gas
Gas Change
Total
Total Change
7/31/2025
5,275,115
19,892,045
25,167,160
12/31/2024
6,134,710
(859,595)
17,717,453
2,174,592
23,852,164
1,314,997
12/31/2023
12,158,338
(6,023,628)
15,622,242
2,095,211
27,780,580
(3,928,416)
12/31/2022
11,633,212
525,126
15,450,554
171,688
27,083,766
696,815
12/31/2021
12,870,253
(1,237,041)
15,086,000
364,554
27,956,253
(872,487)
12/31/2020
14,239,233
(1,368,981)
15,019,173
66,827
29,258,406
(1,302,153)
12/31/2019
12,124,142
2,115,092
13,837,040
1,182,133
25,961,181
3,297,225
12/31/2018
15,559,867
(3,435,725)
12,335,998
1,501,042
27,895,864
(1,934,683)
12/31/2017
23,213,245
(7,653,378)
10,702,689
1,633,309
33,915,934
(6,020,070)
12/31/2016
8,612,801
14,600,444
9,500,074
1,202,615
18,112,875
15,803,059
12/31/2015
6,170,790
2,442,011
9,037,373
462,701
15,208,163
2,904,712
12/31/2014
3,598,821
2,571,969
6,765,165
2,272,208
10,363,986
4,844,177
* 2017's Significant increase in cash balance is due to issuing bonds for the generator project.
Hutchinson Utilities Commission
Cash -Designations Report, Electric
7/31/2025
Change in
Financial
Annual
Balance,
Balance,
Cash/Reserve
Institution
Current Interest Rate
Interest
July 2025
June 2025
Position
�' Rr
Savings, Checking, Investments varies varies varies 25,167,160.42 26,059,835.43 (892,675.01)
Total HUC Operating Funds 25,167,160.42 26,059,835.43 (892,675.01)
Debt Restricted Requirements
Debt Restricted Requirements
Total Restricted Funds
Bond Covenants - sinking fund
Bond Covenants -1 year Max. P & 1
592,609.37
1,183,256.00
1,775,865.37
494,004.68
1,183,256.00
1,677,260.68
98,604.69
-
98,604.69
Excess Reserves Less Restrictions,
Electric
0.
i 11J! !!1 1 !1
J J
Operating Reserve
Min 60 days of 2025 Operating Bud.
4,578,753.17
4,578,753.17
-
Rate Stabalization Funds
$400K-$1.2K
1,443,969.35
1,169,595.93
274,373.42
PILOT Funds
Charter (Formula Only)
1,345,802.00
1,345,802.00
-
Catastrophic Funds
Risk Mitigation Amount
800,000.00
800,000.00
Capital Reserves
5 Year CIP (2025-2029 Fleet & Infrastructure Maintenance)
2,750,000.00
2,750,000.00
-
Total Designated Funds
10,918,524.52
10,644,151.10
274,373.42
YE
YE
YE
YE
YTD
APPA Ratio
HUC
2021
2022
2023
2024
2025
5K-10K Cust.
Target
Debt to Asset Ratio (* w/Gen.) 32.2%
34.8%
34.0%
33.9%
33.4%
39.8%
Current Ratio 5.70
4.96
4.35
2.38
2.21
3.75
RONA -1.2%
-4.2%
-0.9%
-2.1%
0.7%
NA
�p,
Hutchinson Utilities Commission
Cash -Designations Report, Gas
7/31/2025
Change in
Financial
Annual
Balance,
Balance,
Cash/Reserve
Institution
Current Interest Rate
Interest
July 2025
June 2025
Position
51' Rr
Savings, Checking, Investments varies varies varies 25,167,160.42 26,059,835.43 (892,675.01)
Total HUC Operating Funds 25,167,160.42 26,059,835.43 (892,675.01)
Debt Restricted Requirements
Bond Covenants - sinking fund
1,353,833.32
1,171,916.65 181,916.67
Debt Restricted Requirements
Bond Covenants -1 year Max. P & 1
2,072,000.00
2,072,000.00 -
Total Restricted Funds
3,425,833.32
3,243,916.65 181,916.67
Excess Reserves Less Restrictions,
Gas
16,466,211.67
16,788,073.12 (321,861.45)
1 1 JJJ1 111 1 11
J J
Operating Reserve
Min 60 days of 2025 Operating Bud.
1,963,816.00
1,963,816.00
Rate Stabalization Funds
$200K-$600K
615,294.19
615,294.19
PILOT Funds
Charter (Formula Only)
596,824.00
596,824.00
Catastrophic Funds
Risk Mitigation Amount
200,000.00
200,000.00
Capital Reserves
5 Year CIP (2025-2029 Fleet & Infrastructure Maintenance)
700,000.00
700,000.00
Total Designated Funds
4,075,934.19
4,075,934.19
YE
YE
YE
YE
YTD
HUC
2021
2022
2023
2024
2025
AGA Ratio
Target
Debt to Asset 28.8%
26.5%
21.0%
15.5%
12.9%
35%-50%
Current Ratio 4.79
4.06
4.61
5.08
6.68
1.0-3.0
RONA 2.9%
3.0%
6.2%
9.1%
4.1%
2%-5%
Notes/Graphs:
ELECTRIC DIVISION
Operating Revenue
July 2025
CLASS
AMOUNT
KWH
/KWH
Street Lights
20.65
379
$0.0545
Electric Residential Service
$668,211.69
6,461,171
$0.1034
All Electric Residential Service
$20,314.04
184,217
$0.1103
Electric Small General Service
$186,231.67
1,810,855
$0.1028
Electric Large General Service
$830,147.83
9,815,630
$0.0846
Electric Large Industrial Service
$705,592.30
8,962,000
$0.0787
Total
$2,410,518.18
27,234,252
$0.0885
Power Adjustment
$0.00000
Rate Without Power Adjustment
$0.08851
Electric Division Year -to -Date
® 2025 $ Amount ❑ 2024 $ Amount ® 2025 KWH110 ❑ 2024 KWH110
20,000,000
18,000,000
16,000,000
14,000,000
12,000,000
10,000,000
8,000,000
6,000,000
4,000,000
2,000,000
0
Residential All Elec. Resid. Small Gen. Srv. Large Gen. Srv. Large Industrial Sales For Resale Total
NOTE: This graph includes sales for resale (capacity and energy sales) but excludes street lights and security lights
NATURAL GAS DIVISION
Operating Revenue
July 2025
CLASS
AMOUNT
MCF
/MCF
Residential
$120,402.62
6,161
$19.5414
Commercial
$81,379.14
7,467
$10.8982
Large Industrial
$19,246.65
3,809
$5.0524
Large Industrial Contracts
$291,204.25
44,505
$6.5432
Total
$512,232.66
61,943
$8.2694
Fuel Adjustment-$3.18000
Rate Without Fuel Adjustment $11.44942
Natural Gas Division Year -to -Date
❑ 2025 $ Amount ❑ 2024 $ Amount m 2025 MCF ❑ 2024 MCF
8,000,000
7,000,000
6,000,000
5,000,000
4,000,000
3,000,000
2,000,000
1,000,000
0
Gas Residential Gas Commercial Large Industrial Large Industrial Total
Contracts
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Work
Order Description
12204 Cooling Tower Repairs
12402 Plant 1 Combustible Gas Detection System
12403 SWOTS Computer Upgrade U5
12501 Tuck Pointing Phase III
12502 Rubber Roof Repair West Portion of Plant 1
12503 Plant 1 Pump Room Ventilation
12504 Plant 1 Control Panel Upgrade
12505 Unit 1 CO2 System Update Code Compliance
12506 Cooling Tower Recirc and Chem Injection
12507 Plant 1 North Ground Fans
Electric Production
Total
Total
Materials
Labor
Budgeted
Actual
1lifference
$
723,509.18
$
723,509.18
$ -
30,229.71
$
30,229.71
300,000.00
$ 300,000.00
211,341.46
$
(88,658.54)
40,000.00
$ 40,000.00
103,506.51
$
63,506.51
42,000.00
$ 42,000.00
-
$
(42,000.00)
30,000.00
5,000.00
$ 35,000.00
-
$
(35,000.00)
80,000.00
20,000.00
$ 100,000.00
-
$
(100,000.00)
20,000.00
$ 20,000.00
-
$
(20,000.00)
130,000.00
$ 130,000.00
-
$
(130,000.00)
50,000.00
$ 50,000.00
$ -
$
50,000.00
$ 692,000.00
$ 25,000.00
$ 717,000.00
$ 1,068,586.86
$
351,586.86
Work
Order pescrition
22301 Hutch Sub Transformer Upgrade Engineering
22401 Hutch Substation Transformer
22402 McLeod Sub Relay Replacement
22405 3M Sub SCADA Phase 2
22406 HTI Sub SCADA
22501 Pole Repair and Replacement
22502 Station Equipment
22503 Plant 1 Sub Circuit Breakers
22504 Plant 15ub Engineering for Willmar Line
22505 Right of Way Clearing
22506 Install Duct
22507 Ravenwood Circle
22508 Edmonton and Sherwood
22509 New Developments
22510 Ravenwood Circle
22511 Edmonton and Sherwood
22512 Transformer Replacements
22513 Transformer New Developments
22514 Meters
22515 Meter Testing Equipment
22516 Security Lights
22517 LED Street Light Conversion
22518 Reconductor Feeder 16
22519 Reconductor Feeder 16
Electric Distribution
Total
Total
Materials
Labor
Bud ete,d
Actual
Difference
2,179,106.20
2,179,106.20
829,812.43
829,812.43
150,000.00
150,000.00
(150,000.00)
-
878.35
878.3.5
124, 088.95
124,088.95
15,000.00
-
15,000.00
-
(15,000.00)
10,000.00
-
10,000.00
-
(10,000.00)
110,000.00
-
110,000.00
-
(110,000.00)
75,000.00
-
75,000.00
7,206.23
(67,793.77)
-
-
-
3,360.44
3,360.44
18,000.00
65,000.00
83,000.00
21,315.66
(61,684.34)
-
-
-
2,865.05
2,865.05
60,000.00
15,000.00
75,000.00
6,429.10
(68,570.90)
-
-
-
3,269.24
3,269.24
-
-
-
1,045.00
1,045.00
50,000.00
15,000.00
65,000.00
2,512.58
(62,487.42)
60,000.00
15,000.00
75,000.00
456.27
(74,543.73)
36,000.00
-
36,000.00
26,588.00
(9,412.00)
30,000.00
-
30,000.00
-
(30,000.00)
-
-
-
470.25
470.25
175,000.00
35,000.00
210,000.00
17,675.14
(192,324.86)
-
-
-
15,435.64
15,435.64
-
-
7,471.04
(7,471.04)
$ 789,000.00
$ 145,000.00
$ 934,000.00
$ 3,249,985.57
2,315,985.57
Administrative
Total
Work Order Descri tion Bud eted
52303 Replace 226 2012 Dodge RAM 1500
52501 Replace 451 Welding Truck -
52502 Genie AWP 25S DC Manual Lift -
Total
Actual Difference
57,374.57 (57,374.57)
$ 57,374.57 $ 57,374.57
Natural Gas
Work
Total
Total
Order
DescriDtion
Materials
Labor
Budgeted
Actual
Difference
62501
Transmitter Calibration Equipment
8,500.00
•--
8,500.00
1,822.66
(6,677.34)
62502
Misc Developments & System Improvements
25,000.00
5,000.00
30,000.00
18,066.68
(11,933.32)
62503
City Projects
7,000.00
2,000.00
9,000.00
20,888.70
11,888.70
62504
Improvements to Regulator Stations
20,000.00
3,500.00
23,500.00
283.02
(23,216.98)
62505
Service Lines
57,000.00
15,000.00
72,000.00
15,899.10
(56,100.90)
62506
Meters, AW, and All Fittings
250,000.00
10,000.00
260,000.00
3,824.11
(256,175.89)
62507
Residential Regulators
-
-
-
-
_
62508
Industrial Metering and Regulation
25,000.00
3,500.00
28,500.00
490.90
(28,009.10)
62509
Edmonton Development
-
-
-
52.65
52.65
62510
School Road River Crossing
W
-
48 907.42
48 907.42
$ 392,500.00
$ 39,000.00
$ 431,500.00 $
110,235.24 $
(321,264.76)
HUTCHINSON UTILITIES COMMISSION
Board Action Form
�rre tit'
Agenda Item: Review Policies
Presenter: Angie Radke
Agenda Item Type:
Time Requested (Minutes): 5
Review Policies
Attachments: Yes
BACKGROUND/EXPLANATION OFAGENDA ITEM:
As part of HUC's standard operating procedures, a continual policy review is practiced.
This month, the following policies were reviewed and no changes are recommended on
these policies at this time:
i. Hutchinson Utilities Commission
ii. Establishing a New Electric/Natural Gas Account
iii. Deposit Requirement — Residential
iv. Deposit Requirement — Commercial/Industrial
V. Terminating Electric/Natural Gas Service by Customer
vi. Definition of Your Bill
vii. Errors in Billing
viii. Payment of Your Bill
ix. Automatic Bill Payment Plan
X. Budget Payment Plan
xi. Explanation of Billing Procedure
xii. Disconnection of Residential Services by HUC
xiii. Disconnection of Commercial Services by HUC
xiv. After Hours Reconnection Policy
xv. Landlord Acknowledgment
xvi. Inserts with Utility Bills
xvii. Identity Theft — "Red Flag Program"
xviii. Minnesota Cold Weather Rule
xix. Minnesota Government Data Practices Act and Public Records Request
BOARD ACTION REQUESTED:
None
Fiscal Impact:
Included in current budget: Budget Change:
PROJECT SECTION:
Total Project Cost: Remaining Cost:
HUTCHINSON UTILITIES COMMISSION
(Hereafter referred to as HUC)
A five -member Commission governs HUC. The Commission members are appointed by
the Mayor and the City Council to each serve a five-year term. The Commission meets at
3.00 p.m. the last Wednesday of each month. The following policies are reviewed and
approved by the Commission and it reserves the right to make changes, and/or to adopt
new and amended policies, as it deems necessary from time to time. The Commission
also reserves the right to vary from its policies in special circumstances.
HUC is a municipal utility that is owned by its citizens, through the City Council and its
political subdivision, the Hutchinson Utilities Commission.
Public/Customer Hours
Monday through Friday
7.30 a.m. to 4.00 p.m.
Address & Phone
225 Michigan Street SE
Hutchinson, MN 55350-1905
(320) 587-4746
Emergency Service
Electric Outage (320) 234-0544
Gas Emergency 1-877-593-3973
(320) 587-4745
Customer Service (320) 234-0502
Web Address
www.hutchinsonutilities.com
Facebook
@hutchinsonutilitiescommission
Establishing a New Electric/Natural Gas Account
New services and meters are read or installed only during normal business hours. A new
service installation requires a 24-hour notice.
Deposit Requirement — Residential
New Residential Customers:
Application for Service
An application for service is required to be completed and submitted prior to receiving
service. The application shall be accompanied by proof of customer identification,
preferably photo identification.
Deposit
A deposit is required for all new residential customers, prior to the utility account being
established in the customer's name.
HUC will conduct an internal account review for all new customer applications. If the
results of the review indicate the customer has an outstanding balance with HUC for
previously provided services, the outstanding balance shall be paid, in addition to the
required deposit, prior to the customer receiving service.
The amount of the deposit is equal to two times the average monthly bill for the
property/address as determined by HUC. For new residential construction with no billing
history, HUC will determine the rates based on similar construction.
A deposit may only be waived if the customer provides verification of a satisfactory
payment history for the previous 12-month period from their current or previous utility
provider indicating, the customer paid all of their bills on time with no late payment fees
attached, issued a disconnect notice and no delinquent or dishonored payments.
Existing Residential Customers Moving Within Service Territory:
A deposit is not required if the customer has a satisfactory payment history for the
previous 12-month period, as defined previously.
A deposit for existing residential customers moving within HUC service territory will be
required prior to the utilities establishing the new account for any of the following reasons-
1. The customer has been disconnected, issued a disconnect notice or had a
delinquent or dishonored payment in the previous 12 months.
2. Subsequent credit information indicates the initial application for service
was falsified.
3. The customer has the ability to pay for the utility service, but during the cold
weather rule months, had an arrears amount incurred during that period that
was 60 days or more past due.
If a deposit is required of a customer, the following will also apply:
1. If customer has no deposit with HUC, the customer will pay the deposit
amount for the customer's new address.
2. If customer already has a deposit with HUC and this deposit amount is
greater than the new deposit required for the new address, HUC will transfer
the deposit from the customer's previous address to the new address. The
balance of the deposit from the previous address will be applied to the
customer's final bill for the previous address. If there is a remaining credit
balance after paying the final bill, this will be applied to the new address
account.
3. If the customer already has a deposit with HUC and this deposit amount is
less than the new deposit required for customer's new address, HUC will
transfer the deposit from the customer's previous address to the customer's
new address. The customer will pay the balance of the deposit amount for
the customer's new address, prior to the utilities being placed in their name.
If a deposit is required the customer may request a written explanation for the
requirement.
Amount of Deposit: The amount of the deposit is equal to two times the average monthly
bill for the property/address as determined by HUC.
For new residential construction with no billing history, HUC will determine the rates
based on similar construction.
Refusal or Disconnection of Service: HUC may refuse or disconnect residential service
for failure to pay a required deposit.
Interest: Interest earned on a deposit is applied to the account as a credit on a calendar
year basis. The rate of interest is determined by the Minnesota Department of Commerce
and updated annually.
When the customer moves out of the HUC service area, the account is finalized. Any
deposit interest is applied to the account as a credit, and the deposit amount is applied to
the final bill. If this results in a credit balance, a check is issued to the customer for the
credit amount.
Refund: The utility shall refund the deposit of a residential customer after 12 consecutive
months of on -time payments (no late payment fees).
If a customer makes a late payment in the initial 12 months of service, the deposit will be
retained, until such time as the customer makes 12 consecutive monthly on -time
payments and incurs no late payment fees.
If the customer provides a payment history from their previous provider, and the payment
history indicates no late payment fees and no dishonored checks, then HUC will refund
the deposit. HUC must receive this information from the customer within 30 days of
customer moving into our services.
Refund at Termination of Service: On termination of residential service, and if the
customer has a deposit with HUC, HUC shall credit the deposit, with accrued interest, to
the customer's final bill and return any remaining balance within 30 days of issuing the
final bill.
Method of Refund: Any deposit amount and interest earned refunded to a residential
customer shall be refunded to the customer's account as a credit unless requested by the
customer to be refunded by check.
Deposit Requirement — Commercial/Industrial
Application for Service
An application for service is required to be completed and submitted prior to receiving
service. The application shall be accompanied by proof of customer identification,
preferably photo identification, and their Federal Tax ID number.
Deposit
A deposit is required for all Commercial/Industrial customers, prior to the utility account
being established in the customer's name.
HUC will conduct an internal account review for all new customer applications. If the
results of the review indicate the customer has an outstanding balance with HUC for
previously provided services, the outstanding balance shall be paid, in addition to the
required deposit, prior to the customer receiving service.
Existing Commercial/Industrial Customers Moving Within Service Territory: A deposit will
be waived if the Commercial/Industrial customer has a 24-month payment history with
HUC indicating the Commercial/Industrial customer has not been disconnected, issued a
disconnect notice or issued any dishonored checks.
A deposit for existing Commercial/Industrial customers moving within HUC service
territory will be required prior, to customer having utilities placed in their name, for the
following reasons-
1. If the customer has been disconnected, issued a disconnect notice or any
dishonored payment in the previous 24 months.
2. Subsequent credit information indicates the initial application for service
was falsified.
If a deposit is required of a customer, and;
1. If a customer has no deposit with HUC, the customer will pay the deposit
amount for the customer's new address.
2. If a customer has a deposit with HUC and this deposit amount is greater
than the new deposit required for customer's new address, HUC will transfer
the deposit from the customer's previous address to the customer's new
address. The balance of the deposit at the customer's previous address will
be applied to the customer's final bill for the previous address. If there is a
remaining credit balance after paying the final bill, this will be applied to the
new address account.
3. If a customer has a deposit with HUC and this deposit amount is less than
the new deposit required for customer's new address, HUC will transfer the
deposit from the customer's previous address to the customer's new
address. The customer will pay the balance of the deposit amount for the
customer's new address, prior to the utilities being placed in their name.
If a deposit is required, the customer may request a written explanation for the
requirement.
Amount of Deposit: The deposit shall be equal to the two highest bills for the past 12
months rounded to the nearest dollar. In the event that the building will be used for a
different purpose than that of the previous tenant/owner, then similar use will be taken
into consideration to determine the amount of deposit.
The deposit may also be made by posting a performance bond or an Irrevocable Letter
of Credit from an FDIC insured financial institution. These options will not earn any interest
and will be terminated after 24 consecutive months of timely payments.
In the event of a new building with no billing history, then similar construction will be used
to establish the average monthly usage.
Refusal or Disconnection of Service: Commercial/Industrial service may be refused or
disconnected for failure to pay a required deposit.
Interest: Interest earned on deposits is applied to the account as a credit on a calendar
year basis. The rate of interest is determined by the Minnesota Department of Commerce
and HUC obtains that information annually.
When the Commercial/Industrial customer moves out of the HUC service area, the
account is finalized. Any deposit with interest is applied to the account as credit, and the
deposit amount is applied to the final bill. If this results in a credit balance, a check is
issued to the customer for that credit amount.
Refund: HUC shall refund the deposit of a Commercial/Industrial customer after 24
consecutive months of on -time payments (no late payment fees).
If a customer is late in making payment, then the deposit will be retained, until such time
as the customer makes 24 consecutive monthly on -time payments (no late payment fees).
Refund at Termination of Service: On termination of Commercial/Industrial service, and if
the customer has a deposit with HUC, HUC shall credit the deposit, with accrued interest,
to the customer's final bill and return any remaining balance within 30 days of issuing the
final bill.
Method of Refund: Any deposit amount and interest earned refunded to a
Commercial/Industrial customer shall be refunded to the customer's account as a credit
unless requested by the customer to be refunded by check.
Terminating Electric/Natural Gas Service by Customer
When the utility service is shut off due to a customer's request, the electric meter will be
removed and the gas meter will be turned off and locked. The electric meter socket and
gas meter valve will have a blue seal placed on them.
At the time a customer requests the service be turned on, HUC personnel will install the
electric meter and unlock the natural gas meter valve.
It is the customer's responsibility to turn on the natural gas meter valve and to light the
pilot lights on all natural gas appliances, where appropriate. In the event the customer is
unable to perform these tasks, it is the customer's responsibility to contact a plumbing or
heating contractor to complete this work.
Upon the request of a customer, utility services may be temporarily terminated and billing
suspended for a specified period of time due to illness, vacation, and/or seasonal use.
Temporary terminations are charged to the customer at the rate of $40 to disconnect and
$40 to reconnect.
A. Termination for Renters
Electric and natural gas meters will be read and the final bill calculated when a
renter informs HUC they no longer wish to retain HUC services.
B. Termination for Residential/Commercial Owners
Electric and natural gas will be shut off when the property owner requests HUC to
disconnect services. For continuous service, the new owner must call HUC at a
minimum of 24 hours in advance of the requested disconnect date, and make the
necessary arrangements to have the electric/natural gas services transferred into
their name. This eliminates terminating services at that address.
C. Termination for Electrical Work
If a homeowner needs an electric meter disconnected to do any electrical work, HUC will
disconnect/reconnect the meter at no charge to the customer. Once the work is
completed, HUC will need a copy of the State Board of Electricity Certificate of Inspection,
before HUC will reconnect the electric meter.
Definition of Your Bill
Your bill provides:
• Account number
• Due date
• Payment due
• Pre -authorized payment to be drawn from your bank on due date (from
checking/saving account)
• Budget amount due if on the budget plan
• Name/mailing address
• Service address
• Electric and fuel cost adjustments, if any
• PIN #
• Reading dates
• Days used
• Previous and current readings
• Usage
• Previous balance
• Payments made and date paid
• Electric and/or gas meter charges
• Amount charged to each meter
• Sales tax/Local tax/County tax
• Any miscellaneous/trip charges
• Account balance
• Perforated top stub to remit with payment for timely and proper posting
• If applicable, a message on the bottom of the statement indicating past due amount
Meters are read approximately every 30 days. Estimated readings may also be taken if
access to the meter is not possible or the meter has stopped working.
Errors in Billing
Overcharged customer accounts will be credited on the next statement or refunded on
the final billing.
Overcharges may only be refunded within three years of the billing error occurrence.
Undercharged customer accounts may be billed for a correction within one year of the
billing error occurrence and may be billed on a separate invoice, with an explanation of
charges.
Payment of Your Bill
Payments are due by the date indicated on the statement.
Payment Locations
• HUC business office at 225 Michigan Street Southeast
• Drop box at either the HUC business office or Hutchinson City Center
Payment Methods
• Cash, check or money order
• automated phone system at (320)587-4746, Option
VISA/MasterCard/Discover/E-check
• automatic bank payment plan(Savings/Checking Account)
• online at www.hutchinsonutilities.com
• online reoccurring credit card payment
• text using Invoice Cloud
E-1-41 1117
When paying in any manner other than cash, no change will be given. No second party
or post-dated checks will be accepted and checks will not be held.
An invalid payment due to nonsufficient funds or other circumstances is treated as a non-
payment. If notification of the invalid payment is received by HUC, the customer will be
charged a $30 processing fee.
If paying by reoccurring credit/debit card, the customer needs to cancel their credit/debit
card immediately if there has been an address change.
When there is a change in the credit/debit card information that is used for reoccurring
payments, the customer will be required to update the system with the new credit/debit
card information.
For billing questions, contact HUC customer service via e-mail at
HUCbilling@hutchinsommn.gov
Automatic Bill Payment Plan
Customers may authorize automatic bill payment through ACH withdrawals from a
checking/savings account, or with the use of a credit/debit card. These payments are
withdrawn on the date the bill is due.
To authorize the withdrawals or automatic payment from a checking/savings account, the
customer must complete an Authorization form, which is available at the HUC business
office or on the HUC website.
To authorize automatic payment with a reoccurring credit/debit card, visit the HUC
website under `Pay Your Bill'.
If paying by reoccurring credit/debit card, the customer needs to cancel their credit/debit
card immediately if there has been an address change.
When there is a change in the credit/debit card information that is used for reoccurring
payments, the customer will be required to update the system with the new credit/debit
card information.
Setting up, changing and cancelling reoccurring credit/debit card information can only be
completed by the customer.
The customer will receive their monthly utility billing statement showing the payment
amount to be withdrawn. The customer may contact the HUC Customer Service
Department before the amount is withdrawn to dispute the billing or with any questions.
The customer will have approximately 10 days to review their bill before the money is
withdrawn.
If a customer's payment is dishonored for two consecutive months, the customer will be
removed from the automatic payment plan and so notified. A service charge of $30 will
be assessed to the customer's account for each dishonored payment occurrence.
Budget Payment Plan
A budget payment plan is available to residential customers who have been at their
present location for a minimum of 12 continuous months. Procedures are in place for
setting up and reviewing the budget payment plan calculation. Changes to the budget
payment amount are made at the discretion of the Customer Service Department based
on the customer's average bill from the previous 12 months. Customers will be notified,
in writing, of any changes. A customer may concurrently participate in the budget payment
plan by automatic bank payment plan or recurring credit cards.
Explanation of Billing Procedure
A bill for services is sent to the address provided by the customer approximately 3 to 5
days after the meters have been read. The customer has approximately 10 days to pay
the bill in full by the stated due date. In accordance with state law, the City of Hutchinson
and its related entities shall have 35 days to pay bills in full.
Bills paid after the due date will incur the following charges:
• A 1 % per month late payment charge on any unpaid balance.
• A $15 processing fee.
A late notice warning of pending disconnection is mailed to the customer and provides
the customer with at least 30 days after the notice has been mailed to pay the bill or
contact the Customer Service Department to make other arrangements. Examples of
other arrangements may include establishing a budget payment plan or payments by
other agencies on the customer's behalf. Failure to make payment by the stated due date
and time will be considered a violation of the notice of pending disconnection. If full
payment or other arrangements have not been made by the deadline, HUC personnel are
sent to the meter location to disconnect utility services (see disconnection of services
section).
IT IS THE CUSTOMER'S RESPONSIBILITY TO PAY BILLS ON TIME AND IN FULL.
A dishonored payment will be assessed a $30 processing fee.
A dishonored payment made to avoid disconnection, to get reconnected, or for a deposit
for service will be assessed a $30 processing fee; plus:
a. A $40 trip charge to deliver a door hanger, a notice advising the customer
they have 24 hours to make the full notice payment. Acceptable forms of
payment include cash, money order or credit card.
b. A $40 trip charge to disconnect service if payment is not received in the
form of cash, money order or credit card.
C. A $40 trip charge to reconnect service with payment made in the form of
cash, money order or credit card.
IT IS THE CUSTOMER'S RESPONSIBILITY TO KEEP HUC FULLY ADVISED OF
ANY CHANGE OF ADDRESS.
Disconnection of Residential Services by HUC
1. Residential utility service may be disconnected for any of the following reasons:
• Failure to pay by the deadline on a delinquent account or failure to comply with the
terms of the budget payment plan.
• Failure to contact HUC to gain protection from disconnection under the Cold
Weather Rule.
• Failure to maintain the payment agreement established under the Cold Weather
Rule.
• Failure to comply with deposit requirement.
• Failure to pay for merchandise or charges for non -utility service billed by HUC.
• Payment of bill with a dishonored check.
• Failure to provide authorized utility personnel access to utility equipment.
• HUC shall disconnect residential utility service, without notice, where service has
been reconnected without HUC's authorization.
• HUC shall disconnect residential utility service, without notice, where it has
reasonable evidence that utility service is being obtained by potentially unsafe
devices or potentially unsafe methods that stop or interfere with the proper
metering of the utility service.
• HUC may disconnect residential utility service, without notice, where a dangerous
condition exists for as long as the condition exists.
• At the request of the property owner, as long as it's currently in owner's name and
no tenant occupies property.
• At the request of the realtor/bank, as long as it's currently in their name.
• If an account owner or property owner does not notify us, within three (3) business
days following disconnection of service for non-payment, a final bill will be
processed and the account will be closed.
2. HUC must have a Landlord Agreement on file acknowledging that landlord/owner will
be responsible for all utility charges after the read-out date requested by a tenant.
Failure of the landlord/owner to execute this form will lead to a shut off of services on
the read-out date requested from tenant.
3. For all items mentioned in number 1 and 2 above, a disconnect/reconnect fee shall be
applied. The disconnect/reconnect fee is as follows:
• A $40 trip charge to disconnect.
• A $40 trip charge to reconnect, payment shall be made with cash, money order or
credit card during regular business hours.
• After hours reconnection will follow the After Hours Reconnection Policy.
4. In the event that the customer pays after the deadline given on the disconnect letter,
and the payment is processed before physical disconnection, a $40 Removal from
Disconnect List Fee will be applied to their account.
5. If a realtor/bank requests to have service reconnected for one day in order to perform
an inspection, a $40 trip charge to reconnect and a $40 disconnect charge will be
applied.
6. In the event of unauthorized use of, or tampering with the equipment of HUC, a
tampering charge of $100 will be assessed to the customer's account. The appropriate
law enforcement agency will be notified. HUC reserves the right to charge the
customer for the cost of repairs to the equipment of HUC.
7. A dishonored payment will be assessed a $30 processing fee.
8. A dishonored payment to avoid disconnection, or to get reconnected, will be assessed
a $30 processing fee; plus:
• A $40 trip charge to deliver a door hanger, giving customer 24 hours to make
payment good with cash, money order or credit card.
9. HUC is not required to furnish residential service under conditions requiring operation
in parallel with Backup generating equipment connected to the customer's system if
such operation is hazardous or may interfere with its own operations or service to
other customers or operation as a condition or rendering service under such
circumstances.
FAILURE TO RESPOND TO THE DISCONNECT NOTICE SET FORTH ON THE BILL
OR FAILURE TO PAY FOR SERVICES RENDERED BY HUC MAY RESULT IN THE
DISCONNECTION OF SERVICES TO THE PROPERTY WITHOUT ANY ADDITIONAL
NOTICE TO THE CUSTOMER. IT IS THE CUSTOMER'S RESPONSIBILITY TO PAY
FOR SERVICES RENDERED AND TO ADVISE HUC OF ANY CHANGE IN ADDRESS.
NEITHER HUC NOR THE CITY OF HUTCHINSON, NOR ANY OF THE AGENTS,
EMPLOYEES OR REPRESENTATIVES OF THE CITY OF HUTCHINSON OR HUC,
WILL BE RESPONSIBLE FOR ANY DAMAGES OR CLAIMS INCURRED AS A RESULT
OF THE DISCONNECTION OF SERVICES.
Residential utility service may not be disconnected or refused for any of the following
reasons:
• Delinquency in payment for services by a previous occupant of the premises to be
served.
• Failure to pay for a different rate classification of utility service.
• Failure to pay the account of another customer as guarantor thereof.
• Failure to pay charges arising from any underbilling occurring more than 1 year
prior to the current billing and due to any misapplication of rates or faulty metering.
• If a customer is on the Budget Payment Plan and has a credit balance on account.
• Tenant pays current month on account in landlord's name.
Disconnection of Commercial Services by HUC
1. Commercial utility service may be disconnected for any of the following reasons:
• Failure to pay by the deadline on a delinquent account.
• Failure to comply with deposit requirement.
• Failure to pay for merchandise or charges for non -utility service billed by HUC.
• Payment of bill with a dishonored check.
• Failure to provide authorized HUC personnel access to utility equipment.
• HUC shall disconnect commercial utility service, without notice, where service has
been reconnected without HUC's authorization.
• HUC shall disconnect commercial utility service, without notice, where it has
reasonable evidence that utility service is being obtained by potentially unsafe
devices or potentially unsafe methods that stop or interfere with the proper
metering of the utility service.
• HUC may disconnect commercial utility service, without notice, where a dangerous
condition exists for as long as the condition exists.
• At the request of the property owner, as long as it's currently in owner's name and
no tenant occupies property.
• At the request of the realtor/bank, as long as it's currently in their name.
2. HUC must have a Landlord Agreement on file acknowledging that landlord/owner will
be responsible for all utility charges after the read-out date requested by a tenant.
Failure of the landlord/owner to execute this form will lead to a shut off of services on
the read-out date requested from tenant.
3. For all items mentioned in number 1 and 2 above, a disconnect/reconnect fee shall be
applied. The disconnect/reconnect fee is as follows:
• A $40 trip charge to disconnect.
• A $40 trip charge to reconnect, payment shall be made with cash, money order or
credit card during regular business hours.
• After hours reconnection will follow the After Hours Reconnection Policy.
4. In the event that the customer pays after the deadline given on the disconnect letter,
and the payment is processed before physical disconnection, a $40 Removal from
Disconnect List Fee will be applied to their account.
5. If a realtor/bank requests to have service reconnected for one day in order to perform
an inspection, a $40 trip charge to reconnect and a $40 disconnect charge will be
applied.
6. In the event of unauthorized use of, or tampering with the equipment of HUC, a
tampering charge of $100 will be assessed to the customer's account. The appropriate
law enforcement agency will be notified. HUC reserves the right to charge the
customer for the cost of repairs to the equipment of HUC.
7. A dishonored payment will be assessed a $30 processing fee.
8. A dishonored payment made to avoid disconnection, or to get reconnected, will be
assessed a $30 processing fee; plus:
• A $40 trip charge to deliver a door hanger, giving customer 24 hours to make
payment good with cash, money order or credit card.
9. HUC is not required to furnish commercial service under conditions requiring operation
in parallel with Backup generating equipment connected to the customer's system if
such operation is hazardous or may interfere with its own operations or service to
other customers or operation as a condition or rendering service under such
circumstances.
FAILURE TO RESPOND TO THE DISCONNECT NOTICE SET FORTH ON THE BILL
OR FAILURE TO PAY FOR SERVICES RENDERED BY HUC MAY RESULT IN THE
DISCONNECTION OF SERVICES TO THE PROPERTY WITHOUT ANY ADDITIONAL
NOTICE TO THE CUSTOMER. IT IS THE CUSTOMER'S RESPONSIBILITY TO PAY
FOR SERVICES RENDERED AND TO ADVISE HUC OF ANY CHANGE IN ADDRESS.
NEITHER HUC NOR THE CITY OF HUTCHINSON, NOR ANY OF THE AGENTS,
EMPLOYEES OR REPRESENTATIVES OF THE CITY OF HUTCHINSON OR HUC,
WILL BE RESPONSIBLE FOR ANY DAMAGES OR CLAIMS INCURRED AS A RESULT
OF THE DISCONNECTION OF SERVICES.
Commercial utility service may not be disconnected or refused for any of the following
reasons:
• Delinquency in payment for services by a previous occupant of the premises to be
served.
• Failure to pay for a different rate classification of utility service.
• Failure to pay the account of another customer as guarantor thereof.
• Failure to pay charges arising from any underbilling occurring more than 1 year
prior to the current billing and due to any misapplication of rates or faulty metering.
• Tenant pays current month on account in landlord's name.
After Hours Reconnection Policy
No after hours reconnections will be done from 9.00 p.m. to 7.30 a.m.
After hours reconnection fees:
A $150 Reconnection Fee will be charged for any reconnection that is done:
• From 5.00 p.m. to 9.00 p.m. on Monday through Friday
• From 7.30 a.m. to 9.00 p.m. on Saturdays
A $200 Reconnection Fee will be charged for any reconnection that is done:
• From 7.30 a.m. to 9.00 p.m. on Sundays or Holidays
Payments must be made prior to reconnecting utilities. Office hours are 7.30 a.m. to 4.00
p.m. Monday through Friday, excluding holidays. After hour payments can only be made
with credit card, debit card or electronic check.
Holidays include the following: New Year's Day, Martin Luther King Day, President's Day,
Memorial Day, Juneteenth, Independence Day, Labor Day, Veterans Day, Thanksgiving
Day, Christmas Eve Day, and Christmas Day.
Landlord Acknowledgement
A signed Landlord Acknowledgement provides the following:
• Confirmation and documentation of the landlord/owner.
• Request of HUC to provide utility service to tenants.
• The understanding that the tenant will be responsible for all utility costs between
the date service is required by the tenant and the date the tenant requests read-
out of services.
• The landlord/owner agrees to be responsible for and to pay all utility charges from
the read-out date given by the tenant until services are established with a new
tenant.
• The understanding that failure to pay these charges could result in disconnection
of electric service. HUC is not responsible for any damages alleged to be caused
by service disconnection. Disconnection/reconnection fees apply.
• The landlord/owner has the option to contact HUC to confirm that the utility service
has been placed in the tenant's name.
• The landlord /owner can request the disconnection of services as long as the
account is in the landlord's/owner's name. Disconnection/reconnection fees apply.
Inserts with Utility Bills
Generally, only material which applies directly to HUC business may be inserted into
monthly utility bill mailings. HUC may approve the inclusion of other items, as appropriate.
Identity Theft — "Red Flag Program"
It shall be the policy of HUC to establish an identity theft prevention program, also known
as the "Red Flag Program".
HUC has an identity theft program in place called the "RED FLAG PROGRAM", pursuant
to the Federal Trade Commission's Red Flags Rule, which implements Section 114 of the
Fair and Accurate Credit Transactions Act of 2003. Internal procedures have been
established whereby employees of HUC have been trained on how to recognize and what
procedures to follow if the employee suspects an identity theft is taking place.
Implementation of the Red Flag Program is the responsibility of the Account Supervisor.
Administration and maintenance of the Red Flag Program is the responsibility of the
Financial Manager.
Minnesota Cold Weather Rule
2021 Minnesota Statutes
216B.097 Cold Weather Rule; Cooperative or Municipal Utility
Subdivision 1. Application; notice to residential customer.
(a) A municipal utility or a cooperative electric association must not disconnect
and must reconnect the utility service of a residential customer during the period
between October 1 and April 30 if the disconnection affects the primary heat source
for the residential unit and all of the following conditions are met:
(1) The household income of the customer is at or below 50 percent of the state
median household income. A municipal utility or cooperative electric association
utility may (i) verify income on forms it provides or (ii) obtain verification of income
from the local energy assistance provider. A customer is deemed to meet the income
requirements of this clause if the customer receives any form of public assistance,
including energy assistance, that uses an income eligibility threshold set at or below
50 percent of the state median household income.
(2) A customer enters into and makes reasonably timely payments under a
payment agreement that considers the financial resources of the household.
(3) A customer receives referrals to energy assistance, weatherization,
conservation, or other programs likely to reduce the customer's energy bills.
(b) A municipal utility or a cooperative electric association must, between
August 15 and October 1 each year, notify all residential customers of the provisions
of this section.
Subdivision 2. Notice to residential customer facing disconnection.
(a) Before disconnecting service to a residential customer during the period
between October 1 and April 30, a municipal utility or cooperative electric
association must provide the following information to a customer:
(1) a notice of proposed disconnection;
(2) a statement explaining the customer's rights and responsibilities between
August 15 — October 1;
(3) a list of local energy assistance providers;
(4) forms on which to declare inability to pay; and
(5) a statement explaining available time payment plans and other opportunities
to secure continued utility service.
(b) At the same time that notice is given under paragraph (a), the utility must
also give written or electronic notice of the proposed disconnection to the local
energy assistance provider and the department.
Subdivision 3. Restrictions if disconnection necessary.
(a) If a residential customer must be involuntarily disconnected remotely using
advance metering infrastructure or physically at the property being disconnected
between October 1 and April 30 for failure to comply with subdivision 1, the
disconnection must not occur:
(1) on a Friday, unless the customer declines to enter into a payment agreement
offered that day in person or via personal contact by telephone by a municipal utility
or cooperative electric association;
(2) on a weekend, holiday, or the day before a holiday;
(3) when utility offices are closed; or
(4) after the close of business on a day when disconnection is permitted, unless
a field representative of a municipal utility or cooperative electric association who is
authorized to enter into a payment agreement, accept payment, and continue
service, offers a payment agreement to the customer.
Further, the disconnection must not occur until at least 30 days after the notice
required in subdivision 2 has been mailed to the customer or 15 days after the notice
has been personally delivered to the customer.
(b) The customer must not be disconnected until the utility attempts to confirm
whether the residential unit is actually occupied, which the utility may accomplish
by.
(1) visiting the residential unit; or
(2) examining energy usage data obtained through advanced metering
infrastructure to determine whether there is energy usage over at least a 24-hour
period that indicates occupancy.
(c) A utility may not disconnect a residential customer who is in compliance with
section 21613.098, subdivision 5.
(d) If, prior to disconnection, a customer appeals a notice of involuntary
disconnection, as provided by the utility's established appeal procedure, the utility
must not disconnect until the appeal is resolved.
(e) For the purposes of this section, "advance metering infrastructure" means
an integrated system of meters, communication networks, and data management
systems that enables tow -way communication between a utility and its customers.
Subdivision 4. Cost Recovery.
A municipal utility or cooperative electric association may recover the
reasonable costs of disconnecting and reconnecting a residential customer, based
on the costs of providing notice to the customer and other entities and whether the
process was accomplished physically at the property being disconnected or
reconnected or remotely using advanced metering infrastructure.
Minnesota Government Data Practices Act and Public Records Request
HUC is in compliance with Minnesota Government Data Practices Act and Public Records
Request.
Billing information is available upon signing `Consent To Release Private Data' form.
Forms are available at the office of HUC.
Business information is available upon signing `Information Disclosure Request' form.
Forms are available at the office of HUC.
HUTCHINSON UTILITIES COMMISSION
^I'�xP61Tti'°"
Board Action Form
Agenda Item: Req #10337 - Plant #1 Substation circuit breakers
Presenter: D. Lang
Agenda Item Type:
Time Requested (Minutes): 5
New Business
Attachments: No
BACKGROUND/EXPLANATION OFAGENDA ITEM:
Requisition #10337 is for the purchase of three 13.8kV roll -in replacement circuit
breakers made by ABB for the Plant #1 Substation. Also included in the price is the cost
for an ABB technician to travel to the site to fit the breakers in each breaker cell.
These ABB circuit breakers will replace the existing General Electric circuit breakers
which have been in service for 40+ years and have had mechanical problems in the
recent past, even with routine maintenance.
HUC has periodically been replacing the GE breakers at the Plant #1 substation with the
ABB breakers due to their specific retrofit compatibility with the GE "Magne-Blast"
breaker and switchgear. The circuit breakers at the Plant #2 Substation were replaced
five years ago with similar units.
WESCO is the regional distributor for ABB and the sole supplier for these retrofit
breakers.
*2025 capital improvement project*
AUG 2025
BOARD ACTION REQUESTED:
Approve requisition #10337 - Plant #1 Substation circuit breakers
Fiscal Impact: $118,822
Included in current budget: Yes Budget Change:
PROJECT SECTION:
Total Project Cost: Remaining Cost: $0
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COMMERCIAL AND TECHNICAL TENDER
Prepared for:
Hutchinson Utilities Commission
Date: 8/6/2025
A66 Inc.
Prepared by:
WESCO Distribution, Inc.
In response to your request for quotation we are pleased to offer the following per WESCO Terms
and Conditions:
www.wesco. com/termsof sale
ABB Region BDM: ABB Tender ID Date Validity
TB-QT-25- 8/6/2025 10/5/2025
7963350.A
ABB Inc.
Page 1 of 13 Electrification Service
2300 Mechanicsville Road
Florence, SC 29501
Your
Reference
Number
GE AM
Magneblast
Phone: (843) 413-4700
Fax: (843) 413-4850
TABLE OF CONTENTS
1.0 INTRODUCTION.............................................................3
2.0 BASE SCOPE EQUIPMENT...................................................3
3.0 CLARIFICATIONS............................................................3
4.0 PRICING....................................................................6
5.0 RENEWAL PARTS Et ACCESSORIES...........................................9
6.0 TERMS AND CONDITIONS .................................................. 11
1.0 Introduction
1.1 ABB Electrification Service is a leading manufacturer of low and medium voltage
replacement circuit breakers. Based on long-time experience and know-how, ABB
developed roll -in replacement retrofit solutions specially tailored to most existing
limited and obsolete medium voltage circuit breakers that were produced by ABB
and other manufacturers. As a result, ABB can offer the opportunity to eliminate
outdated air magnetic technology with the latest vacuum interrupting technology.
The result is a significant improvement in reliability, safety, maintenance, and
performance.
2.0 Base Scope Equipment
2.1 New Replacement Circuit Breaker - We propose to replace the existing circuit
breaker(s) with RMVAC, medium voltage roll -in replacement circuit breaker(s). The
RMVAC replacement breaker(s) brings all the benefits of increased performance
with reduced maintenance intervals.
2.2 New Vacuum Breaker Element -The operating mechanism consists of a magnetic
actuator, control module with sensor systems, storage capacitor, and is rated for 3-
5 cycle operation. Supplementary components are available for manual opening.
2.3 Breaker Carriage and Interlocks - A rugged steel frame with mechanical and
electrical interlock safety features to fit your existing switchgear cell with little or
no modifications.
2.4 All new components - The breaker element, breaker frame, interlocks, primary
bushing, secondary disconnects and wiring are all completely new.
2.5 Non -hygroscopic Bushings - All circuit breaker bushings will be new and feature
track resistant, non -hygroscopic epoxy construction.
2.6 Design Testing - Roll -in replacement circuit breakers offered conform to the
applicable portions of ANSI C37.59, C37.04, and C37.06.
2.7 Production Testing - Production testing of the roll -in replacement elements is in
accordance with the applicable portions of ANSI C37.09. Objective evidence of that
testing is provided with each circuit breaker upon request.
3.0 Clarifications
3.1 In order to ensure proper fit and tolerances, ABB may recommend a customer site
visit after receipt of order to verify design requirements. If verification is necessary,
a short outage will be required for this purpose. Customer will be notified of this
requirement immediately upon receipt of order and all required technical
information (Section 3.3 below.)
3.1.1- New Circuit Breaker Design - If new Circuit breaker design is required of ABB
Per Customer Specifications - ABB will request Customer's Approval and Sign off
prior to manufacturing new breaker. Shipment schedules will be determined from
the date of ABB Engineering and Customer Approval acceptance.
3.1.2 -fir®t®type - If ABB determines a prototype is required for new design; ABB
will require a customer site visit for test fitting and measurements. A complete bus
outage is required for said site visit. Customer will be notified of this requirement
immediately.
For existing designs, prototypes are not required.
3.2 On -site installation and commissioning or supervision provided by ABB personnel
consists of 1.) Providing technical assistance to customer personnel to verify that all
safety interlocks operate as designed with the corresponding cell, 2.) Perform
verification of open, close and motor charging operations and 3.) Perform activities
to verify that breakers rack into and out of the switchgear compartment cell.
3.2.1 NOTE - Installation and Commissioning
3.2.1.1 As switchgear cells may vary and/or been modified over the years
of service, adjustments may be necessary to ensure a proper fit and
operation of the new replacement breaker. Because of this, ABB
recommends that Supervision or Installation and Commissioning be
performed only by factory trained ABB personnel.
3.2.1.2 When Installation and Commissioning is purchased in conjunction
with the quoted breakers, an additional (4) years extended warranty will
apply and will include both parts and service, when the equipment is
subjected to normal operating conditions and is properly maintained by the
customer.
3.2.1.3 ABB is not responsible for any damages resulting from improper
installations performed by third parties that result in damage or mis-
operation of the equipment.
3.3 Customer is responsible for providing ABB Inc. with an accurate control wiring
drawing for breaker and cubicle so that ABB Inc. can ensure secondary contacts
correctly match the existing switchgear control scheme.
3.4 The ABB Medium Voltage Service Safety Manual states that no ABB employee shall
work on energized equipment. This requirement also applies to situations where
an ABB Field Service Engineer is overseeing and supervising the work of others.
Although ABB understands each customer has their own safety plan in place, it is our
recommendation that all work on switchgear be performed with the bus de -energized.
Under no circumstance shall an ABB representative rack a breaker into an energized
cell. When an ABB representative is observing the racking process, he/she shall not
be within the flash protection boundary. If the flash protection boundary has not
been calculated, then the ABB representative shall exit the area/building until the
racking process is completed.
3.5 Customer additional responsibilities:
3.5.1 Free and clear access to switchgear for inspection.
3.5.2 Disposal of old breaker(s).
3.5.3 For order entry acceptance - completion of attached Specification
Worksheet required
3.5.4 Submittal of Wiring Diagrams. Project schedule will be placed on hold if the
Wiring Diagrams are not received within the requested time frame.
3.5.5 Schedule required outage for Installation / Commissioning or Installation /
Commissioning Supervision.
3.6 Delivery
3.6.1 Quoted lead times are based on current production levels.
3.6.2 Actual lead times are dependent on available production space at time of
order entry and/or release to manufacturing.
3.6.3 "Shipment clock" will not begin until receipt of all required technical
information from customer and completion of any required site visit for
engineering measurements.
Customer Requirement
Specification must be completed prior to placing an order. Any selected spares will
incur additional costs. Reference Section 5.0 or contact factory for pricing.
(Double click on Icon to complete)
o rPoiiµ
MV RiR Spec Sheet
F-MKT-01-02 R07.pdf
4.0 Pricing
Item
Qty
Product Type
Net Price Each
USD)
Item Total
(LISD)
1
1
RIR AM 13.8 750 1200A
$35,377.00
$35,377.00
RIR RMVAC AM 13.8 750 1200A
GE MAGNEBLAST AM-13.8-750 1200A
(same as order WD14170)
REQUIRED:
-COMPLETION OF SPECIFICATION WORKSHEET UPON
ORDER ENTRY
-WIRING DIAGRAMS UPON ORDER ENTRY
ABB Internal Order Entry Codes:
Product Code: [9AAF400373] - Circuit Breakers /
Service / Extension, Upgrades and Retrofits /
Retrofits
Source Location: [9AAE300864] - United States -
Florence - 3442 MV Service
1 B
1
RIR AM 13.8 750 1200A
$33,608.00
$33,608.00
RIR RMVAC AM 13.8 750 1200A
OPTIONAL END OF LIFE TAKE BACK PROGRAM
DISCOUNTED PRICE
CUSTOMER SHALL RETURN BACK THE LEGACY
BREAKERS PER ORDER QUANTITY TO ABB INC,
FLORENCE, SC WITHIN ONE MONTH OF RETROFIT
INSTALLATION.
ABB WILL MANAGE END -OF -LIFE SERVICES FOR THE
RETURNED BREAKER(S).
ABB ORDER ENTRY to add $0 LINE item (PER ORDER
QUANTITY) for tracking returned breakers with Part
number: SERVICE-TBP-AM
REQUIRED:
-COMPLETION OF SPECIFICATION WORKSHEET UPON
ORDER ENTRY
-WIRING DIAGRAMS UPON ORDER ENTRY
ABB Internal Order Entry Codes:
Product Code: [9AAF400373] - Circuit Breakers /
Service / Extension, Upgrades and Retrofits /
Retrofits
Source Location: [9AAE300864] - United States -
Florence - 3442 MV Service
2
2
RIR AM 13.8 750 2000A
$38,560.00
$38,560.00
RIR RMVAC AM 13.8 750 2000A
GE MAGNEBLAST AM-13.8-750 2000A
(same as order WD14170)
REQUIRED:
-COMPLETION OF SPECIFICATION WORKSHEET UPON
ORDER ENTRY
-WIRING DIAGRAMS UPON ORDER ENTRY
ABB Internal Order Entry Codes:
Product Code: [9AAF400373] - Circuit Breakers /
Service / Extension, Upgrades and Retrofits /
Retrofits
Source Location: [9AAE300864] - United States -
Florence - 3442 MV Service
2B
2
RIR AM 13.8 750 2000A - Option B
$36,633.00
$36,633.00
RIR RMVAC AM 13.8 750 2000A
OPTIONAL END OF LIFE TAKE BACK PROGRAM
DISCOUNTED PRICE
CUSTOMER SHALL RETURN BACK THE LEGACY
BREAKER(S) (PER ORDER QUANTITY) TO ABB INC,
FLORENCE, SC WITHIN ONE MONTH OF RETROFIT
INSTALLATION.
ABB WILL MANAGE END -OF -LIFE SERVICES FOR THE
RETURNED BREAKER(S).
ABB ORDER ENTRY to add $0 LINE item (PER ORDER
QUANTITY) for tracking returned breakers with Part
number: SERVICE-TBP-AM
REQUIRED:
-COMPLETION OF SPECIFICATION WORKSHEET UPON
ORDER ENTRY
-WIRING DIAGRAMS UPON ORDER ENTRY
ABB Internal Order Entry Codes:
Product Code: [9AAF400373] - Circuit Breakers /
Service / Extension, Upgrades and Retrofits /
Retrofits
Source Location: [9AAE300864] - United States -
Florence - 3442 MV Service
2
1
MV INSTALL
$6,325.00
$6,325.00
MV It AND COMMISSIONING SUPPORT or
SUPERVISION
"CUSTOMER MUST SPECIFY WHICH IS REQUIRED ON
PO"
(1) FIELD TECHNICIAN; LOCAL TECH
(2) 8-HOUR WEEKDAY(S) ON SITE
(Excludes ABB recognized holidays)
"Any additional time and material will be invoiced
separately. Quoted pricing is assuming local
resource. Any additional travel will need to be
quoted separately.
REQUIRED
" WHEN ORDERING ANY RIR CIRCUIT BREAKER
INSTALLATION AND COMMISSIONING and/or
SUPERVISION MUST BE PERFORMED BY ABB CERTIFIED
PERSONNEL AND ORDERED IN CONJUNCTION WITH RIR
BREAKERS.
PART NUMBER MUST APPEAR ON PURCHASE ORDER AS
A SEPARATE LINE ITEM.
Scope of work:
0 Removal of existing breakers and set aside for
storage or removal by the customer
0 Prepare switchgear cubical to accept the new RIR
breakers and make upgrade recommendations where
required.
0 Identify all electrical and mechanical connections
that may be in place at each mounting position
during the disassembly process of existing circuit
breakers.
0 Safety Interlock verification
0 Functional operation
0 Operations training for (2) customer facility
technicians
An outage is required.
ABB Internal Order Entry Codes:
Product Code: [9AAF400377] - Medium Voltage /
Circuit Breakers / Service / Spares and Consumables
Source Location: [9AAE300864] - United States -
Florence - 3442 MV Service
Cancellation Schedule
25% After Order Entry
50% After release to order of material
75% After start of Fabrication
4.1 Freight is Ex -works Factory Florence, SC Not Unloaded Prepaid and Add
4.2 Lead time is in 18 weeks after receipt of order and all customers supplied technical
data. 33 ,ti d 3 5 foi I �u11 d i" ,,lmr^II4".I lm i,"IIi d al,ao
4.3 Additional days of installation and commissioning supervision and /or actual installation
and commissioning services can be quoted based on customer installation schedule.
See attachment Field service Rate Sheet
5.0 Renewal Parts and Accessories
RMVAC - Loose Spares (if required, please add the additional line items on PO
referencing the part number, quantities, and dollar amount)
NOTICE - PARTS VARY PER BREAKER STYLE (NOT ALL ARE REQUIRED)
Description
Part Number
No. Per Breaker
Pricing Each
Manual Opening Handle (Required). Please note (1)
is included on each order at no additional charge
19540G00
1 per lineup
$545.00
HV (125/250 VAC/VDC) Control Board
19911P40
1
$1,450
LV 48V DC Control Board
19911P30
1
$1,450
AUX. Switch 5 NO Contacts (Please verify compatibility
with factory before ordering)
GCE7002397RO119
1 or more
$138.00
AUX. Switch 5 NC Contacts (Please verify compatibility
with factory before ordering)
GCE7002397RO124
1 or more
$138.00
Membrane Switch Assembly. Reverse Colors
19949G20
1
$460.00
Membrane Switch Assembly. Standard Colors
19949G10
1
$460.00
ABB RIR Lifting Device Assembly (Please verify
compatibility with factory before ordering)
1VAF005343R0002
1 per lineup
$1,114.00
Storage Capacitor (Set of 2)
1VCF359899S0151
1
$929.00
Remote Operating Umbilical Handheld Device
**Breaker(s) must be equipped with Umbilical Breaker
Harness (lVAF203245A0001); see Breaker Add-ons
below
1VAF203242A0001
1 per lineup
$2,500.00
RMVAC - Breaker Add-ons (if required, please add $ value to the total breaker price and
make a note on the PO for the breaker(s) to include within BOM)
NOTICE - PARTS VARY PER BREAKER STYLE (NOT ALL ARE REQUIRED)
Description
Part Number
No. Per Breaker
Pricing Each
Remote Operating Umbilical Breaker Harness
1VAF203245A0001
1
$800.00
Rapid Capacitor Discharge Switch
1VAF101292A0001
1
$777.00
NOTICE:
RMVAC - AC CHARGE W/ DC TRIP
It has been a common design practice in the US to specify switchgear circuit breakers with AC power
for the close and motor charging circuit, and DC power for the trip circuit. This decision allows the
station batteries to be a smaller capacity, since they are only used in the dedicated DC power
circuit. The source for the AC power is often the station itself, the voltage being transformed down
from the primary station power. In the event of a station blackout, AC control power is usually
lost. The trip (opening) circuit is still operational because it is working off the battery. Operational
procedures at customers often required all breakers be opened before power is restored, so the
power can be brought on slowly to prevent an additional blackout.
However, due to the nature of RMVAC roll -in replacement breakers, these same practices cannot be
used. It has been the Medium Voltage Services practice to power the control boards in these
breakers with the existing charging motor power (AC) because it is convenient to do so; no wiring
changes would be required in the switchgear. The control board must have this power at all times
in order to operate the breaker, because the power maintains a charge on the capacitors. If the
existing charging motor power is lost, then sending a DC signal to the trip circuit will have no effect
- the breaker will not open.
Customers must be aware of this RMVAC feature. This will educate the customer to one of these
options:
1 - Do nothing, loss of tripping abilities with loss of AC is not a concern.
2 - Rewire the cell so DC power can be used to power the control board (connect DC power to the
close and existing "charge" circuits).
3 - Change operating procedures.
4 - Add the Powered Remote Umbilical Device to add for local control (see section 5.0 for part
numbers and pricing)
6.1 This proposal contains proprietary information and is considered confidential to ABB Inc.
It is submitted upon the expressed condition that the information contained herein will
not be released to competitors or otherwise used directly or indirectly in a detrimental
way to the interest of ABB Inc.
6.2 All products are offered in accordance with ABB Inc. (Service and Related Products
Conditions of Sale Form 7-2001 Issue) attached hereto.
6.3 This proposal shall remain valid for 60 days from the date of issue.
6.4 Consideration on 2019-nCoV (Coronavirus Outbreak)
If after submission of ABB's bid or during the term of the agreement there are any
measures taken by authorities, by ABB or others in connection with the current
coronavirus (2019-nCoV) outbreak which affect the performance of the agreement, the
parties agree that ABB will be entitled to cost compensation, time extension, or other
reasonably required contract adjustments if any consequences in any way related to the
coronavirus outbreak lead to delays in delivery of goods or provision of services or
otherwise affect ABB's contractual obligations or duties.
6.5 Consideration for Material Supply
The Parties are aware of the shortage of raw materials, electronic components
worldwide which are likely to last for the foreseeable future, as well as of market
fluctuations in the availability and cost of other raw materials, commodities, other
critical components, and transportation capacities. Notwithstanding anything to the
contrary in the contract/terms and conditions/purchase order, if after the date of
ABB's proposal / offer or during the term of the performance of the contract/purchase
order there are any changes to availability and / or market conditions for electronic
components, raw materials, commodities and transportation capabilities directly or
indirectly affecting ABB's performance, ABB shall be entitled to relief in the schedule
of the performance or delivery of the directly or indirectly affected scope of work
under the contract/purchase order. In such circumstances, the Parties shall meet
without delay and discuss in good faith to find a mutually agreeable solution, with
equitable adjustment to the contract/purchase order date of delivery or completion.
Customer hereby acknowledges and agrees that in said circumstances ABB may not be
able to comply with the originally agreed delivery or completion schedule and that ABB
shall not be liable for any liquidated or actual damages in connection thereto.
6.6 Consideration for Transportation
The offer is based on Incoterms as stated. Due to current fluctuations in transportation
cost, the transportation cost may be given as a separate line item and is to be
considered a non -binding estimate based on current market prices. At the time of
delivery, ABB will use reasonable efforts to get optimum transport arrangements and
the actual cost will be invoiced by ABB to the Purchaser. In no case will ABB be liable
for any increase in transportation cost at the time of delivery.
Electrificatilloin Serviice, U.S A. A1111101
Service Rates Jain 1, 20,2�5
ABB Ilnhm. mainlairs a complele staff of Feld SerAce 1persorinel who are averlsible to pccvde advisofy assistanc�e, installation,
unspectlor, commissionling• testing. troulbleshoctling, stem up, engineering studiles, maintenance sind repair sere« cesof both AIBB
and non-ABB electrical apparatus.
B-Houir Dailv Rates Typicali IFielld Services, Repairs, aind Product Support
Clamifficaloom Weekday l tuirdmy Sunday w
U-mw P MxfiL�Valur,. e
Lx�iw Al gSwk rluu I tr4em, Gig, SwIchpow, pvanecfiwe Rfpbys arcl chcul4 Greake"s
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FIrrxpAirmma Ue Lagk u.'opplrcdms
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Page 12 of 13
IHI UT iU H II HI S U HII
UT'IIILIITIIIE'S
a I(,� ii'JG 11�p Ili II I! � �a II ii';� If1i
WESCO RECEIVABLES CORP
LOCKBOX 771751
1751 SOLUTIONS CENTER DR
CHICAGO, IL 60677
Note
Description:
ABB RIR Circuit Breakers
PURCHASE REQUISITION
HUTCHINSON UTILITIES COMMISSION
225 MICHIGAN ST SE
HUTCHINSON, MN 55350
Phone:320-587-4746 Fax:320-587-4721
Date
Requisition No.
08/07/2025
010337
Required by:
Requested by:
Mang
Item
No.
part No.
Description
Qty
Unit
Due Date
Unit Price
Ext. Amount
ABB RIR RMVAC CIRCUIT BREAKER - 1200A -
15KV. 750 MVA
1
125VDC CONTROL VOLTAGE
1.00
EA
$35,377.000
$35,377.00
REPLACING GE MAGNEBLAST 13.8-750
MFG. PART:
ABB RIR RMVAC CIRCUIT BREAKER - 2000A -
15KV. 750 MVA
2
125VDC CONTROL VOLTAGE
2.00
EA
$38,560.000
$77,120.00
REPLACING GE MAGNEBLAST 13.8-750
MFG. PART:
MV INSTALLATION AND COMMISSIONING -
(1) FIELD TECHNICIAN
3
(2) DAYS ON SITE
1.00
EA
$6,325.000
$6,325.00
MFG. PART:
Total: 118,822.00
Date Printed: 08/21/2025 Requisitioned By: DLang Page: 1/1