04-30-2025 HUCCPHUTCHINSON UTILITIES COMMISSION
AGENDA
REGULAR MEETING
April 30, 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. Section 4 of Exempt Handbook
ii. Section 4 of Non -Exempt Handbook
b. Approve Changes
i. Compensation Plan (Exempt and Non -Exempt)
ii. Travel Expenses (Exempt and Non -Exempt)
7. UNFINISHED BUSINESS
8. NEW BUSINESS
a. Review of 2024 Annual Benchmarking Report
b. Review of 2024 Safety Award of Excellence
C. Approve Req#010216 — Renegade Professional Services
d. Approval of City of Fairfax Natural Gas Facilities Maintenance
Agreement
e. Approval of Highland Park Industrial, LLC Natural Gas Transportation
and Commodity Purchase Agreement
f. Approve Req#010227 — School Road Bridge Project
g. Approve Req#010225 Phase 3 Tuck Pointing with Additional Brick
Repair — Plant 1
h. Set a Special Meeting for Cash Flow Projection Discussion
9. ADJOURN
MINUTES
Regular Meeting — Hutchinson Utilities Commission
Wednesday, March 26, 2025
Call to order — 3:00 p.m.
President Matt Cheney called the meeting to orde
Cheney; Vice President Troy Pullis; Secretary
Lambert; GM Jeremy Carter; Attorney Marc Sebora
& Schmiesing Audit Firm
Absent: Commissioner Kathy Silvernale
r. Members present: President Matt
Don Martinez; Commissioner Tom
Justin McGraw with Conway, Deuth
1. Conflict of Interest
President Cheney declared conflict of interest in voting on agenda item 2b Ratify
Payment of Bills; President Cheney is owner of Redline Systems which is on this
month's payment of bills. President Cheney will be abstaining from Agenda item 2b.
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 2024 FINANCIAL AUDIT —PRESENTATION BY JUSTIN MCGRAW
Justin McGraw with Conway, Deuth & Schmiesing Audit Firm presented the 2024
Hutchinson Utilities Commission Independent Audit Report. Mr. McGraw also
provided Financial statement packets that show more detail along with how the
review went. Mr. McGraw stated the audit was conducted in accordance with the
Generally Accepted Accounting Standards and Government Auditing Standards.
The financial statements of the Commission are presented fairly in the firms' opinion.
Mr. McGraw reviewed the Statement of Net Position. Assets decreased slightly in
2024 with liabilities increasing. Mr. McGraw reviewed the Cash and Investment
Balances. Restricted and Designated balances remained similar with Operating
balances decreasing.
Mr. McGraw reviewed the Electric and Natural Gas Divisions Operating Revenues
and Expenses.
Mr. McGraw summarized the Communications portion of the report with no
recommendations for the upcoming year. Mr. McGraw stated the audit went well and
the Staff was very helpful.
Motion by Commissioner Pullis, second by Commissioner Martinez to Approve the
2024 Financial Audit. Motion carried unanimously.
4. Approve Financial Statements
Mr. Martig presented the Financial Statements. Electric Division Net Profit increased
by $104K over February 2024. An additional $150k in PCA was collected compared
to last year. Purchased Power increased by $182K but was due to a true up of past
expenses that actually lowered purchased power by $120k in February 2024.
Natural Gas Division Net Income increased by $374K mostly due to increased usage
with a much colder month compared to 2024.
GM Carter reviewed year to date usage on both the Electric and Natural Gas
Divisions. GM Carter recapped discussion from last month regarding the Rate
Stabilization fund and PCA. GM Carter reviewed Investments.
Motion by Commissioner Lambert, second by Commissioner Pullis to Approve the
Financial Statements. Motion carried unanimously.
5. Open Forum
6. Communication
a. City Administrator —Matthew Jaunich —
i. A couple of City Developments coming this year
'7=big015607
i. Dan Lang, Engineering Services Manager — Nothing to report
ii. Dave Hunstad, Electric Transmission/Distribution Manager — Nothing to
report
iii. Mike Gabrielson, Production Manager —
1. Provided update on Caterpillar Engine Oil leaks at Plant; Ziegler
Caterpillar is installing the fix which is being covered on warranty.
2. Side Stream project completed
3. Stack Testing completed
iv. Jared Martig, Financial Manager- Nothing to report
c. Human Resources — Angie Radke -
i. Working on Natural Gas Manager position
d. Legal — Marc Sebora —
i. Nothing to report
e. General Manager — Jeremy Carter
i. Scheduling a tour for Plants 1 and 2
ii. Working on Natural Gas Prepaid items
iii. Working on Tolling Agreement
iv. Prospective customer looking to come to town — Staff is in the preliminary
stages of working on a draft energy agreement
v. Sent Commissioners Cash Flow projections- looking at having a Special
meeting in soon
vi. Natural Gas Transmission TVC Update
vii. Preliminary stages of permitting to relocate pipeline off of School Road
Bridge
viii. Sent Commissioners Owatonna Survey to review
7. Policies
a. Review Policies
2
i. Section 3 of Exempt Handbook
ii. Section 3 of Non -Exempt Handbook
No changes recommended at this time
b. Approve Changes
i. Flextime Program (Exempt)
ii. Attendance/Tardiness (Exempt and Non -Exempt)
iii. Rest Periods (Non -Exempt)
iv. Use of Facilities During Off -Duty Hours (Non -Exempt)
Ms. Radke spoke of the policy changes. There are no substance changes to the
policies, all policies are still applicable. Changes are to remove the word Director
from policies.
Motion by Commissioner Martinez, second by Commissioner Lambert to Approve
Policy Changes. Motion carried unanimously.
8. Unfinished Business
9. New Business
a. Approval of HTI Substation Transformer Repair
Mr. Hunstad presented approval of HTI Substation Transformer Repair. The HTI
Substation transformer was taken out of service in January due to a nitrogen leak.
Global Transformer Solutions completed an inspection of the transformer. Staff
and Global Transformer Solutions are recommending the attached transformer
repairs.
Motion by Commissioner Pullis, second by Commissioner Lambert to Approve
HTI Substation Transformer Repair. Motion carried unanimously.
10. Adjourn
There being no further business, a motion by Commissioner Martinez, second by
Commissioner Pullis to adjourn the meeting at 3:29p.m. Motion carried unanimously.
ATTEST:
Matt Cheney, President
3
Don Martinez, Secretary
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HUTCHINSON UTILITIES COMMISSION
COMBINED DIVISIONS
FINANCIAL REPORT FOR MARCH, 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)
25% of Year Comp.
2025 2024 Di . %Chna 2025 2024 Di %Chna Full Yr Bud %of Bud
$ 3,057,679 $ 3,056,078 $ 1,602
$ 289,413
$ 272,006
$ 17,407
$ 169,924
$ 136,822
$ 33,103
$ 60,639
$ 60,383
$ 255
$ 54,824
$ 806,441
$ (751,617)
$ 75,172
$ 70,926
$ 4,246
$ 3,707,652
$ 4,402,656
$ (695,004)
0.1%
$ 10,478,985
$
9,874,381
$ 604,605
6.1%
$ 38,041,145
27.5%
6.4%
$ 901,947
$
982,200
$ (80,253)
(8.2%)
$ 3,490,250
25.8%
24.2%
$ 517,365
$
493,451
$ 23,914
4.8%
$ 2,071,218
25.0%
0.4%
$ 181,917
$
181,150
$ 767
0.4%
$ 727,666
25.0%
(93.2%)
$ 142,110
$
883,832
$ (741,722)
(83.9%)
$ 483,841
29.4%
6.0%
$ 204,186
$
254,105
$ (49,919)
(19.6%)
$ 633,457
32.2%
(15.8%)
$ 12,426,510
$
12,669,119
$ (242,609)
(1.9%)
$ 45,447,577
27.3%
$ 624,051
$ 636,164
$ (12,112)
(1.90%)
$ 1,931,889
$
1,953,794
$ (21,905)
(1.1%)
$ 8,248,534
23.4%
$ 1,639,079
$ 1,695,203
$ (56,124)
(3.3%)
$ 6,184,277
$
6,016,908
$ 167,369
2.8%
$ 20,256,167
30.5%
$ 202,369
$ 193,831
$ 8,537
4.4%
$ 555,580
$
558,245
$ (2,665)
(0.5%)
$ 3,015,064
18.4%
$ 59,936
$ 24,054
$ 35,882
149.2%
$ 211,344
$
425,186
$ (213,842)
(50.3%)
$ 1,284,200
16.5%
$ 349,379
$ 364,484
$ (15,105)
(4.1%)
$ 1,048,188
$
1,093,489
$ (45,301)
(4.1%)
$ 4,310,000
24.3%
$ 222,524
$ 222,269
$ 255
0.1%
$ 667,573
$
666,807
$ 766
0.1%
$ 2,670,292
25.0%
$ 293,531
$ 291,524
$ 2,007
0.7%
$ 791,945
$
759,552
$ 32,393
4.3%
$ 3,174,901
24.9%
$ 49,688
$ 58,538
$ (8,850)
(15.1%)
$ 149,064
$
175,614
$ (26,550)
15.1%
$ 596,257
25.0%
$ 3,440,558
$ 3,486,067
$ (45,509)
(1.3%)
$ 11,539,859
$
11,649,594
$ (109,735)
(0.9%)
$ 43,555,415
26.5%
$ 267,094
$ 916,589
$ (649,495)
(70.9%)
$ 886,651
$
1,019,526
$ (132,875)
(13.0%)
$ 1,892,162
46.9%
March
March
i,
YTD
YTD
2025
2024
Change
2025
2024
Change
Gross Margin %:
34.5%
34.1%
0.4%
32.4%
29.4%
2.9%
Operating Income Per Revenue $ (%):
5.7%
3.2%
2.4%
6.2%
0.9%
5.2%
Net Income Per Revenue $ (%):
7.2%
20.8%
-13.6%
7.1%
8.0%
-0.9%
2025
HUC
Budget
Target
34.2%
3.5%N
4.2%N
uuIIUuIINNI
HUTCHINSON UTILITIES COMMISSION
ELECTRIC DIVISION
FINANCIAL REPORT FOR MARCH, 2025
2025
2024
Di .
%Chna
2025
2024
Di
%Chna
Full YrBud
%of Bud
Electric Division
Customer Revenue
$
1,878,997
$ 1,796,431
$ 82,566
4.6%
$ 5,866,663
$ 5,438,516
$ 428,147
7.9%
$ 25,609,217
22.9%
Sales for Resale
$
289,413
$ 272,006
$ 17,407
6.4%
$ 901,947
$ 982,200
$ (80,253)
(8.2%)
$ 3,490,250
25.8%
Other Revenues
$
25,494
$ 23,583
$ 1,911
8.1%
$ 60,288
$ 51,037
$ 9,251
18.1%
$ 191,126
31.5%
Interest Income
$
38,980
$ 36,857
$ 2,123
5.8%
$ 106,275
$ 131,235
$ (24,959)
(19.0%)
$ 333,457
31.9%
TOTAL REVENUES
$
2,232,884
$ 2,128,877
$ 104,007
4.9%
$ 6,935,174
$ 6,602,989
$ 332,185
5.0%
$ 29,624,050
23.4%
Salaries & Benefits
$
476,245
$ 471,964
$ 4,280
0.9%
$ 1,476,492
$ 1,463,204
$ 13,288
0.9%
$ 5,955,489
24.8%
Purchased Power
$
873,321
$ 853,206
$ 20,115
2.4%
$ 3,091,497
$ 2,814,964
$ 276,533
9.8%
$ 12,605,893
24.5%
Transmission
$
202,369
$ 193,831
$ 8,537
4.4%
$ 555,580
$ 558,245
$ (2,665)
(0.5%)
$ 3,015,064
18.4%
Generator Fuel/Chem.
$
59,936
$ 24,054
$ 35,882
149.2%
$ 211,344
$ 425,186
$ (213,842)
(50.3%)
$ 1,284,200
16.5%
Depreciation
$
251,590
$ 271,753
$ (20,163)
(7.4%)
$ 754,822
$ 815,171
$ (60,349)
(7.4%)
$ 3,200,000
23.6%
Transfers (Elect./City)
$
172,789
$ 172,534
$ 255
0.1%
$ 518,367
$ 517,601
$ 766
0.1%
$ 2,073,468
25.0%
Operating Expense
$
215,669
$ 188,008
$ 27,661
14.7%
$ 534,802
$ 542,767
$ (7,965)
(1.5%)
$ 2,145,148
24.9%
Debt Interest
$
32,771
$ 35,305
$ (2,533)
(7.2%)
$ 98,314
$ 105,914
$ (7,600)
JLZLI
$ 393,257
25.0%
TOTAL EXPENSES
$
2,284,691
$ 2,210,656
$ 74,035
3.3%
$ 7,241,217
$ 7,243,052
$ (1,835)
(0.0%)
$ 30,672,519
23.6%
NET PROFIT/(LOSS)
$
(51,807)
$ (81,779)
$ 29,972
(36.7%)
$ (306,043)
$ (640,063)
$ 334,020
(52.2%)
$ (1,048,469)
29.2%
25% of Year Comp.
2025
2024
Di .
%Chna
2025
2024
Di
%Chna
Full YrBud
%of Bud
Electric Division
Residential
3,870,882
3,880,190
(9,308)
(0.24%)
12,848,558
12,327,574
520,984
4.23%
54,084,350
23.8%
All Electric
218,087
223,106
(5,019)
(2.25%)
932,985
803,294
129,691
16.14%
2,585,300
36.1%
Small General
1,411,375
1,375,180
36,195
2.63%
4,571,410
4,334,116
237,294
5.48%
18,348,996
24.9%
Large General
7,115,490
5,860,143
1,255,347
21.42%
19,039,850
17,360,383
1,679,467
9.67%
83,540,973
22.8%
Industrial
8,104,000
8,240,000
(136,000)
(1.65%)
24,949,000
25,488,000
(539,000)
(2.11%)
113,841,379
21.9%
Total KWH Sold
20,719,834
19,578,619
1,141,215
5.83%
62,341,803
60,313,367
2,028,436
3.36%1
272,400,998
22.9%
March
March
YTD
YTD
2025
HUC
2025
2024
Change
2025
2024
Change
Budget
Target
Gross Margin %:
28.6%
30.9%
-2.3%
26.1%
24.4%
1.7%
27.0%
Operating Income Per Revenue $ (%):
-3.2%
-4.5%
1.3%
-4.9%
-10.5%
5.6%
-3.5%
0%- 1%
Net Income Per Revenue $ (%):
-2.3%
-3.8%
1.5%
-4.4%
-9.7%
5.3%
-3.5%
0%- 1%
Customer Revenue per KWH:
$0.0907
$0.0918
-$0.0011
$0.0941
$0.0902
$0.0039
$0.0940
IIII���I
Total Power Supply Exp. per KWH:
$0.0752
$0.0734
$0.0017
$0.0808
$0.0810
-$0.0002
$0.0784
$0.0784
Net Loss decreased by $29,972 over March 2024. Customer usage and revenues were up but offset some by increased expenses. Generator fuels
were up in large part due to the generators running in order to do RATA testing. Operating expenses were also up due to the $43,000 paid to the company
that performed the RATA testing.
Sales for Resale of $289,413 consisted of $45,163 in market sales, $98,000 in capacity sales to Rice Lake, and $146,250 in capacity sales to AEP. March
2024 Sales for Resale of $272,006 included $27,756 in market sales, $98,000 in capacity sales to Rice Lake, $146,250 in capacity sales to AEP. March 2023
Sales for Resale of $414,879 consisted of $27,034 in market sales, $98,000 in capacity sales to Rice Lake, $146,250 in capacity sales to AEP, and $143,595 in
tolling and energy sales to Dynasty Power.
Overall Purchased Power increased by $20,115. MRES purchases increased by $24,443 and market purchases/MISO costs decreased by $4,328.
The average cost of MISO power was $28.11/mwh (2,184 mwh's purchased), compared to $19.52/mwh (2,346 mwh's purchased) in February 2024.
There was no Power Cost Adjustment for March 2025 leaving the total at $151,798 YTD.
There was no PCA in March 2025 or YTD 2024.
HUTCHINSON UTILITIES COMMISSION
GAS DIVISION
FINANCIAL REPORT FOR MARCH, 2025
25% of Year Comp.
2025
2024
2
%Chna
2025
2024
2 .
%Chna
Full Yr Bud
% of Bud
Gas Division
Customer Revenue
$
1,178,682
$ 1,259,647
$
(80,965)
(6.4%)
$
4,612,322
$
4,435,864
$
176,458
4.0%
$ 12,431,928
37.1%
Transportation
$
169,924
$ 136,822
$
33,103
24.2%
$
517,365
$
493,451
$
23,914
4.8%
$ 2,071,218
25.0%
Electric Div. Transfer
$
60,639
$ 60,383
$
255
0.4%
$
181,917
$
181,150
$
767
0.4%
$ 727,666
25.0%
Other Revenues
$
29,330
$ 782,858
$
(753,527)
(96.3%)
$
81,822
$
832,795
$
(750,973)
(90.2%)
$ 292,715
28.0%
Interest Income
$
36,192
$ 34,069
$
2,123
6.2%
$
97,911
$
122,870
$
(24,959)
(20.3%)
$ 300,000
32.6%
TOTAL REVENUES
$
1,474,768
$ 2,273,779
$
(799,011)
(35.1%)
$
5,491,337
$
6,066,131
$
(574,794)
(9.5%)
$ 15,823,527
34.7%
Salaries & Benefits
$
147,807
$ 164,199
$
(16,393)
(10.0%)
$
455,397
$
490,590
$
(35,193)
(7.2%)
$ 2,293,045
19.9%
Purchased Gas
$
765,758
$ 841,997
$
(76,239)
(9.1%)
$
3,092,780
$
3,201,944
$
(109,164)
(3.4%)
$ 7,650,274
40.4%
Operating Expense
$
77,862
$ 103,516
$
(25,654)
(24.8%)
$
257,143
$
216,785
$
40,358
18.6%
$ 1,029,753
25.0%
Depreciation
$
97,789
$ 92,730
$
5,058
5.5%
$
293,366
$
278,318
$
15,048
5.4%
$ 1,110,000
26.4%
Transfers (City)
$
49,735
$ 49,735
$
(0)
(0.0%)
$
149,206
$
149,206
$
(0)
(0.0%)
$ 596,824
25.0%
Debt Interest
$
16,917
$ 23,233
$
(6,317)
0.0%
$
50,750
$
69,700
$
(18,950)
27.2%
$ 203,000
25.0%
TOTAL EXPENSES
$
1,155,867
$ 1,275,411
$
(119,544)
(9.4%)
$
4,298,642
$
4,406,542
$
(107,900)
(2.4%)
$ 12,882,896
33.4%
NET PROFIT/(LOSS)
$
318,901
$ 998,368
$
(679,467)
(68.1%)l
$ 2,940,631
40.6%
1,192,694 $ 1,659,589 $ (466,894) (28.1%)
25% of Year Comp.
2025 2024 2 %Chnq 2025 2024 p %Chnq Full Yr Bud % of Bud
Gas Division
Residential
46,478,405
46,863,738
(385,333)
(0.82%)
208,661,923
176,074,168
32,587,755
18.51%
435,250,000
47.9%
Commercial
34,023,509
32,828,318
1,195,191
3.64%
147,344,656
122,435,953
24,908,703
20.34%
337,584,000
43.6%
Industrial
80,711,449
80,163,449
548,000
0.68%
282,588,030
252,785,042
29,802,988
11.79%
895,764,000
31.5%
Total CF Sold
161,213,363
159,855,505
1,357,858
0.85%
638,594,609
551,295,163
87,299,446
15.84%
1,668,598,000
38.3%
March
March
YTD
YTD
2025
2025
2024
Change
2025
2024
Change
Budget
Gross Margin %:
43.5%
38.6%
4.9%
40.4%
35.8%
4.6%
48.0%
Operating Income Per Revenue $ (%):
19.4%
14.3%
5.1%
20.2%
15.4%
4.9%
17.0%
Net Income Per Revenue $ (%):
21.6%
43.9%
-22.3%
21.7%
27.4%
-5.6%
18.6%
Contracted Customer Rev. per CF:
$0.0066
$0.0066
$0.0000
$0.0068
$0.0077
-$0.0009
$0.0061
Customer Revenue per CF:
$0.0080
$0.0092
-$0.0012
$0.0075
$0.0083
-$0.0008
$0.0087
Total N.G. Supply Exp. per CF:
$0.0050
$0.0056
($0.0007)
$0.0050
$0.0060
($0.0010)
$0.0048
Notes/Graphs:
March Net Income decreased by $679,467. The biggest reason is the receipt of $752,000 a year ago from Heartland Corn for reimbursement of the
interconnect station.
March 2025 Fuel Credit Adjustment was $1.06754/MCF crediting customers $89,914 for the month and $354,454 YTD.
There was no March 2024 FCA but $150,146 was returned to customers YTD.
HUC
Target
$0.0087
$0.0048
HUTCHINSON UTILITIES COMMISSION
BALANCE SHEET - CONSOLIDATED
MARCH 31, 2025
Electric
Gas
Total
Total
Net Change
Division
Division
2025
2024
Total (YTD)
Current Assets
UnrestrictedlUndesignated Cash
Cash
(1,935,415.34)
14,056,791.61
12,121,376.27
16,380,507.64
(4,259,131.37)
Petty Cash
680.00
170.00
850.00
850.00
-
Designated Cash
Capital Expenditures - Five Yr. CIP
2,750,000.00
700,000.00
3,450,000.00
3,450,000.00
-
Payment in Lieu of Taxes
1,345,802.00
596,824.00
1,942,626.00
1,942,626.00
-
Rate Stabilization - Electric
417,463.11
-
417,463.11
246,729.41
170,733.70
Rate Stabilization - Gas
-
615,294.19
615,294.19
488,671.69
126,622.50
Catastrophic Funds
800,000.00
200,000.00
1,000,000.00
1,000,000.00
-
Restticted Cash
Bond & Interest Payment 2017
394,818.74
-
394,818.74
394,552.08
266.66
Bond & Interest Payment 2012
-
727,666.64
727,666.64
724,600.00
3,066.64
Debt Service Reserve Funds
1,183,256.00
2,072,000.00
3,255,256.00
3,255,656.00
(400.00)
Total Current Assets
4,956,604.51
18,968,746.44
23,925,350.95
27,884,192.82
(3,958,841.87)
Receivables
Accounts (net of uncollectible allowances)
1,902,369.44
1,203,300.57
3,105,670.01
3,901,552.46
(795,882.45)
Interest
74,314.28
74,314.29
148,628.57
141,412.63
7,215.94
Total Receivables
1,976,683.72
1,277,614.86
3,254,298.58
4,042,965.09
(788,666.51)
Other Assets
Inventory
2,088,936.06
550,688.82
2,639,624.88
2,527,375.51
112,249.37
Prepaid Expenses
337,366.76
153,368.84
490,735.60
662,796.18
(172,060.58)
Sales Tax Receivable
407,634.89
-
407,634.89
340,901.51
66,733.38
Deferred Outflows- Electric
346,153.00
-
346,153.00
741,556.00
(395,403.00)
Deferred Outflows - Gas
-
114,253.00
114,253.00
247,185.00
(132,932.00)
Total Other Assets
3,180,090.71
818,310.66
3,998,401.37
4,519,814.20
(521,412.83)
Total Current Assets
10,113,378.94
21,064,671.96
31,178,050.90
36,446,972.11
(5,268,921.21)
Capital Assets
Land & Land Rights
690,368.40
3,899,918.60
4,590,287.00
4,590,287.00
-
Depreciable Capital Assets
94,054,506.97
44,579,509.55
138,634,016.52
157,273,106.24
(18,639,089.72)
Accumulated Depreciation
(48,984,899.85)
(22,546,467.42)
(71,531,367.27)
(92,741,225.85)
21,209,858.58
Construction - Work in Progress
3,480,359.30
24,528.53
3,504,887.83
2,251,264.40
1,253,623.43
Total Net Capital Assets
49,240,334.82
25,957,489.26
75,197,824.08
71,373,431.79
3,824,392.29
Total Assets 59,353,713.76 47,022,161.22 106,375,874.98 107,820,403.90 (1,444,528.92)
Current Liabilities
Current Portion of Long-term Debt
Bonds Payable
Bond Premium
Lease Liability - Solar Array
Accounts Payable
Accrued Expenses
Accrued Interest
Accrued Payroll
Total Current Liabilities
Long -Term Liabilities
Noncurrent Portion of Long-term Debt
2017 Bonds
2012 Bonds
Bond Premium 2012
Pension Liability- Electric
Pension Liability - Electric OPEB
Pension Liability - Nat Gas
Pension Liability - Nat Gas OPEB
Accrued Vacation Payable
Accrued Severance
Deferred Outflows - Electric
Deferred Outflows - Nat Gas
Total Long -Term Liabilities
Net Position
Retained Earnings
Total Net Position
HUTCHINSON UTILITIES COMMISSION
BALANCE SHEET - CONSOLIDATED
MARCH 31, 2025
Electric Gas Total
Division Division 2025
790,000.00
19, 546.00
2,329,912.71
131,085.41
74,417.48
3,344,961.60
11,750,000.00
423,788.16
1,832,248.00
39,880.00
569,807.22
208,347.54
1,294,449.00
16,118,519.92
1,980,000.00
185,608.32
926,246.56
67,666.66
24,851.60
3,184,373.14
2,080,000.00
123, 738.51
610,749.00
13,293.00
169,522.80
37,374.19
431,483.00
3,466,160.50
2,770,000.00
185,608.32
19, 546.00
3,256,159.27
198,752.07
99,269.08
6,529,334.74
11,750,000.00
2,080,000.00
547,526.67
1,832,248.00
39,880.00
610,749.00
13,293.00
739,330.02
245,721.73
1,294,449.00
431,483.00
19,584,680.42
Total Net Change
2024 Total (YTD)
2, 655, 000.00 115, 000.00
185,608.32 -
- 19,546.00
3,506,744.61 (250,585.34)
234,152.09 (35,400.02)
81,989.03 17,280.05
6,663,494.05 (134,159.31)
12,540,000.00
(790,000.00)
4,060,000.00
(1,980,000.00)
766,591.95
(219,065.28)
2,776,372.00
(944,124.00)
64,096.00
(24,216.00)
925,458.00
(314,709.00)
21,365.00
(8,072.00)
718,594.32
20,735.70
153,920.05
91,801.68
998,815.00
295,634.00
332,938.00
98,545.00
23,358,150.32 (3,773,469.90)
39,890,232.24 40,371,627.58 80,261,859.82 77,798,759.53 2,463,100.29
39,890,232.24 40,371,627.58 80,261,859.82 77,798,759.53 2,463,100.29
Total Liabilities and Net Position 59,353,713.76 47,022,161.22 106,375,874.98 107,820,403.90 (1,444,528.92)
Hutchinson Utilities Commission
Cash -Designations Report, Combined
3/31/2025
Financial
Institution
Current Interest Rate
Annual
Interest
Balance,
March 2025
Balance,
February 2025
Change in
Cash/Reserve
Position
Savings, Checking, Investments varies varies varies 23,925,350.95 22,987,255.94 938,095.01
Total Operating Funds 23,925,350.95 22,987,255.94 938,095.01
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)
1,122,485.38 841,564.02 280,921.36
3,255,256.00 3,255,656.00 (400.00)
4,377,741.38 4,097,220.02 280,521.36
6,542,569.17
6,542,569.17 -
1,032,757.30
952,656.51 80,100.79
1,942,626.00
1,942,626.00 -
1, 000, 000.00
1, 000, 000.00
3,450,000.00
3,450,000.00 -
13,967,952.47
13,887,851.68 80,100.79
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
4.05
RONA 0.41%
-1.38%
1.96%
2.63%
0.93%
Change in
Cash Balance (From 12131114 to 313112025)
Month End
Electric
Elec. Change
Natural Gas
Gas Change
Total
Total Change
3/31/2025
4,956,605
18,968,746
23,925,351
12/31/2024
6,134,710
(1,178,106)
17,717,453
1,251,293
23,852,164
73,187
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
3/31/2025
Change in
Financial
Annual
Balance,
Balance,
Cash/Reserve
Institution
Current Interest Rate
Interest
March 2025
February 2025
Position
�' Rr
Savings, Checking, Investments varies varies varies 23,925,350.95 22,987,255.94 938,095.01
Total HUC Operating Funds 23,925,350.95 22,987,255.94 938,095.01
Debt Restricted Requirements
Debt Restricted Requirements
Total Restricted Funds
Bond Covenants - sinking fund
Bond Covenants -1 year Max. P & 1
394,818.74
1,183,256.00
1,578,074.74
295,814.05
1,183,656.00
1,479,470.05
99,004.69
(400.00)
98,604.69
Excess Reserves Less Restrictions,
Electric
3,378,529.77
3,134,528.94
244,000.83
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
417,463.11
337,362.32
80,100.79
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
9,892,018.28
9,811,917.49
80,100.79
Excess Reserves Less Restrictions
& Designations, Electric
(6,513,488.51)
(6,677,388.55)
163,900.04
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%
32.8%
39.8%
pp ppppp
ryry NNNNNNNNNNNN
Current Ratio
5.70 4.96 4.35 2.38
2.45
3.75
RONA
-1.2% -4.2% -0.9% -2.1%
-0.6%
NA
>0%
Hutchinson Utilities Commission
Cash -Designations Report, Gas
3/31/2025
Change in
Financial
Annual
Balance,
Balance,
Cash/Reserve
Institution
Current Interest Rate
Interest
March 2025
February 2025
Position
51' Rr
Savings, Checking, Investments varies varies varies 23,925,350.95 22,987,255.94 938,095.01
Total HUC Operating Funds 23,925,350.95 22,987,255.94 938,095.01
Debt Restricted Requirements
Bond Covenants - sinking fund
727,666.64
545,749.97 181,916.67
Debt Restricted Requirements
Bond Covenants -1 year Max. P & 1
2,072,000.00
2,072,000.00 -
Total Restricted Funds
2,799,666.64
2,617,749.97 181,916.67
Excess Reserves Less Restrictions,
Gas
:0
0.
i 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%
14.1%
35%-50%
Current Ratio 4.79
4.06
4.61
5.08
5.70
1.0-3.0
RONA 2.9%
3.0%
6.2%
9.1%
2.9%
2%-5%
Notes/Graphs:
ELECTRIC DIVISION
Operating Revenue
March 2025
CLASS
AMOUNT
KWH
/KWH
Street Lights
$30,285.68
2,582
$0.0545
Electric Residential Service
$443,653.63
3,870,882
$0.1146
All Electric Residential Service
$23,138.02
218,087
$0.1061
Electric Small General Service
$151,645.01
1,411,375
$0.1074
Electric Large General Service
$613,005.85
7,115,490
$0.0862
Electric Large Industrial Service
$617,269.00
8,104,000
$0.0762
Total
$1,878,997.19
20,722,416
$0.0907
Power Adjustment
$0.00000
Rate Without Power Adjustment
$0.09067
Electric Division Year -to -Date
® 2025 $ Amount ❑ 2024 $ Amount ® 2025 KWH110 ❑ 2024 KWH110
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
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
March 2025
CLASS
AMOUNT
MCF
/MCF
Residential
$379,504.63
46,478
$8.1652
Commercial
$267,220.77
34,024
$7.8540
Large Industrial
$30,003.03
4,093
$7.3295
Large Industrial Contracts
$501,953.76
76,618
$6.5514
Total
$1,178,682.19
161,213
$7.3113
Fuel Adjustment-$1.06750
Rate Without Fuel Adjustment $8.37882
Natural Gas Division Year -to -Date
❑ 2025 $ Amount ❑ 2024 $ Amount m 2025 MCF ❑ 2024 MCF
5,000,000
4,500,000
4,000,000
3,500,000
3,000,000
2,500,000
2,000,000
1,500,000
1,000,000
500,000 -- M--1 1[ U IT
0
1111111111111111111111111111
Gas Residential Gas Commercial Large Industrial Large Industrial Total
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Monthly Report -
Hutchinson Utilities
Commission
Hutchinson Utilities
Commission
Year Minimum duration
2025
Month Maximum duration
03 - March
Annual Report? Top-level Cause
Yes -----
No
Substation
Circuit
Remove Major Events?
Use APPA Event threshol,
IEEE 1366 Statistics
Metric
Mar 2025
Mar 2024
SAIDI
0.107
None
SAIFI
0.00161
None
CAI DI
67
None
ASAI
99.9997%
100%
Momentary Interruptions
0
0
Sustained Interruptions
2
0
Circuit Ranking - Worst Performing
Ranked by Outage Count
Circuit Substation
Fdr#12 Plant 1
Fdr#18 Plant 1
Ranked by Customer Interruptions
Circuit Substation
Fdr#18 Plant 1
Fdr#12 Plant 1
Ranked by Customer Minutes of Duration
Circuit Substation
Fdr#18 Plant 1
Fdr#12 Plant 1
Number of Outages
1
1
Customer Interruptions
8
4
Customer Minutes of Duration
512
292
Historical Monthly SAIDI Chart
20
15
lit
5
0
Apr May
2024 2024
Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar
2024 2024 2024 2024 2024 2024 2024 2025 2025 2025
Historical Monthly SAIFI Chart
SAIDI
of monthly SAIDI values
SAIFI
of monthly SAIFI values
Causes Ranked by Count
Cause Count
Squirrel
Ice
Causes Ranked by Duration
Cause Duration
Squirrel 512
Ice 292
Top 2 Outages for the Month
Customers
Address Interrupted
710 North High 8
Dr
20767 Hwy 15 N 4
Total Customers Affected for the Month:
Average Customers Affected per Outage:
Customer Minutes of
Duration Interruption
64 512
rK��ya
Start Date
03/10/2025
11WKi1920,61
12
s
�t
ff
�` r �" r
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. Section 4 of Exempt Handbook
ii. Section 4 of Non -Exempt Handbook
BOARD ACTION REQUESTED:
None
Fiscal Impact:
Included in current budget: Budget Change:
PROJECT SECTION:
Total Project Cost: Remaining Cost:
EXEMPT
SECTION 4 — WAGE AND SALARY INFORMATION
PAY PERIOD, PAYDAYS
All employees are paid every other Thursday for the two -week period ending the preceding Sunday
at 12:00 midnight. Should a payday fall on a holiday, paychecks/direct deposits will be available
the preceding day.
PAYROLL DEDUCTIONS
HUC is required to deduct federal and state income taxes, Social Security tax, and any court -
ordered deductions such as child support from paychecks/direct deposits. HUC is also required to
deduct the employee's contribution to the Public Employee Retirement Association (PERA).
Other deductions may be made from a paycheck/direct deposit such as deferred compensation, and
insurance premiums. These payroll deductions may be made only with the employee's written
consent.
OVERTIME
Exempt employees may earn compensatory time on an hour -for -hour basis for all hours worked in
excess of 40 hours per week. Exempt employees must use their compensatory time by December
31 of the year in which it is earned or it will be forfeited. Accrued compensatory time shall not be
paid out to exempt employees upon separation from employment.
WORKER'S COMPENSATION
An employee who is injured on the job or becomes ill due to job -related reasons is eligible for
worker's compensation benefits. HUC's worker's compensation insurance provider shall pay the
employee approximately 2/3 of the weekly gross wage or salary lost due to injury or illness and
HUC shall pay the additional 1/3 of the weekly gross wage for up to 120 work days. Thereafter,
the employee may use accrued sick leave, vacation leave, or compensatory time to pay the
additional 1/3 lost wage or salary. PERA and FICA are not deducted from the worker's
compensation portion of the paycheck.
NON-EXEMPT
SECTION 4 — WAGE AND SALARY INFORMATION
PAY PERIOD, PAYDAYS
All employees are paid every other Thursday for the two -week period ending the preceding Sunday
at 12:00 midnight. Should a payday fall on a holiday, paychecks/direct deposits will be available
the preceding day.
PAYROLL DEDUCTIONS
HUC is required to deduct federal and state income taxes, Social Security tax, and any court -
ordered deductions such as child support from paychecks/direct deposits. HUC is also required to
deduct the employee's contribution to the Public Employee Retirement Association (PERA).
Other deductions may be made from a paycheck/direct deposit such as union dues, deferred
compensation, and insurance premiums. These payroll deductions may be made only with the
employee's written consent.
OVERTIME
See Union Contract.
WORKER'S COMPENSATION
An employee who is injured on the job or becomes ill due to job -related reasons is eligible for
worker's compensation benefits. WC's worker's compensation insurance provider will pay
the employee approximately 2/3 of the weekly gross wage or salary lost due to injury or illness
and HUC shall pay the additional 1/3 of the weekly gross wage for up to 120 work days.
Thereafter, the employee may use accrued sick leave, vacation leave, or compensatory time to
pay the additional 1/3 lost wage or salary. PERA and FICA are not deducted from the worker's
compensation portion of the paycheck.
HUTCHINSON UTILITIES COMMISSION
Board Action Form
�rre tit'
Agenda Item: Approve Policy Changes
Presenter: Angie Radke
Agenda Item Type:
Time Requested (Minutes): 5
Approve Policy Changes
Attachments: Yes
BACKGROUND/EXPLANATION OFAGENDA ITEM:
As part of HUC's standard operating procedures, a continual policy review is
practiced. The following revisions to the policies below are recommended.
i. Compensation Plan
ii. Travel Expenses
BOARD ACTION REQUESTED:
Approve Policy Changes
Fiscal Impact:
Included in current budget: Budget Change:
PROJECT SECTION:
Total Project Cost: Remaining Cost:
EXEMPT
COMPENSATION PLAN
The Hutchinson Utilities Commission (HUC) has considered the existing positions for HUC and
the current economic conditions.
For each position there shall be a title, job description, and a pay scale level assigned.
This plan covers all regular full-time, exempt positions/employees only.
Plan Objectives
To establish and maintain a compensation plan that enables HUC to be highly competitive
within our defined industry.
To lead or exceed the market in attracting and retaining qualified, reliable and motivated
employees who are committed to quality and excellence for those we serve.
To ensure, subject to the financial condition of HUC, that employees receive fair and equitable
compensation in relation to their individual contributions to HUC's success.
To follow the principles of pay equity in establishing and maintaining pay relationships among
positions.
To ensure program flexibility necessary to meet changing economic, competitive,
technological, and regulatory conditions encountered by HUC.
To balance compensation and benefit needs with available resources.
Open Salary Range
HUC shall adopt an Open Salary Range compensation plan that will allow for maximum flexibility
since there are not defined or pre -calculated "steps". Employee movement is based solely on
performance. The open salary range concept rewards good and exceptional performers and
advances employees to the market rate more quickly.
Allocation of New Positions
When a new position is created for which no appropriate description exists or when the duties of
an existing position are sufficiently changed so that no appropriate description exists, the
Commission, after recommendation of the General Manager/HR, shall cause an appropriate job
description -specification to be written for said position.
Pay Scales
Pay scales will be adjusted on an annual basis in accordance with adjustments made in the
labor agreement.
Exempt Employees
Each position will have a six-month probationary period. After satisfactory completion of
the probationary period, an increase may be granted as warranted by the annual
performance appraisal. Thereafter, consideration for increases will be given annually at the
first of the year. The General Manager reserves the discretion to adjust individual rates as
required. The Commission will determine any pay increase for the General Manager.
Consideration for market adjustment will be made each January 1.
The General Manager shall maintain the discretion to hire at any point based on the qualifications,
experience, market conditions or other relevant factors, to secure the best candidate for the
position.
Performance Evaluations
For all regular full-time employees, a performance appraisal or evaluation will be made on an
annual basis. An evaluation made by the employee'smanager or supervisor shall be
submitted in writing to the employee and the General Manager. All evaluations will be
forwarded to the Human Resources for filing in the employee files.
Evaluations shall be based upon the performance of the individual in the position measured
against established job performance criteria. Such criteria may include level of knowledge,
skills, ability, quality of work, personal work traits, compliance with established HUC or
departmental rules and regulations or any other criteria that is indicative of performance.
The performance appraisal process is the application of performance standards to past
performance. In appraising an employee, these are the basic levels of performance:
5 — Outstanding Performer — Performance is exceptional in all areas and is recognizable as
being far superior to others.
4 — Exceeds Expectations — Results clearly exceed most positions requirements. Performance
is of high quality and is achieved on a consistent basis.
3 — Solid Performer — Competent and dependable level of performance. Meets performance
standards of the job.
2 — Needs Improvement — Performance is deficient in certain area(s). Improvement is
necessary.
1— Unsatisfactory — Results are generally unacceptable and require immediate improvement.
Results - The results of the exempt employee's evaluation will normally have the following
effect on his/her salary per the following Merit Increase Guide below. The percent increase
given to an employee within a certain performance score range will be based on where the
employee's current salary is at in their respective pay grade range approved by the Commission
Performance Score:
0 to 1.0
1.01 to 2.0
2.01 to 3.0
3.01 to 4.0
% of Increase Range
0% - 0%
0% - 2%
1% - 5%
2% - 6%
4.01 to 5.0
Market Conditions
3% - 7%
Notwithstanding any language to the contrary, HUC retains the right to deviate from the pay
plan when, in the sole judgment of the Commission, market conditions or other circumstances
dictate such a decision. Market conditions are defined as the availability of a particular
position.
Eligible employees include all non -represented employees except those who have been subject
to disciplinary action per the HUC Employee Handbook as follows:
An additional consequence of disciplinary action more severe than oral reprimand will be the
permanent loss of the January 1 market adjustment in the calendar year following such
disciplinary action. This will occur unless the DiFeetof: Mwiiger in charge and the General
Manager decide otherwise.
Annual Market Adjustment Consideration
On an annual basis, a market survey will be reviewed. As a result of the current year
marketplace, an additional increase may be deemed necessary. The General Manager maintains
final approval responsibility for salary increases.
Any market adjustment on January 1 of any year shall be separate and apart from the individual
merit increases. In determining a recommendation for an annual market adjustment, the
General Manager shall consider, at least the following information:
1. U.S. and Minneapolis/St. Paul consumer -priced index changes (CPIU & CPIW)
2. Social Security calculation of cost of living increase
3. Unemployment rate
4. Employee turnover rate
5. Area wage survey
6. Legislative growth factor constraints
7. Bargaining Unit Increase
Modification of the Plan
HUC reserves the right to modify any or all of the components or to vary from any of the
components of the Compensation Plan at its discretion and at any time.
Review of the Plan
It is recommended that HUC's General Manager/HR annual review and maintain its Position
Classification Plan. As deemed necessary, the General Manager/HR would recommend any
changes to the Commission. It is further recommended that a comprehensive review be
completed every five years.
TRAVEL EXPENSES
Business Related Vehicle Operation
Travel within the State shall be by HUC vehicle if possible.
If a HUC vehicle is not available for in -State travel, or is not practical to use, then an employee
may seek approval from Dk:ee�oF oF Manager to use a personal vehicle for transportation. The
following rules shall apply:
• The employee shall be reimbursed for mileage at the current IRS mileage reimbursement
rate.
• HUC is not liable for damage to personally owned vehicles used for HUC business.
• HUC may request proof of insurance from employees who use personally owned vehicles
on HUC business.
• Travel to and from events should be by the most direct route possible.
• Employees are expected to return in a timely manner.
Travel outside of the State must be approved by the employee's [)iFee�oF of Manager. If it is
appropriate to drive, the employee shall follow the same rules as travel within the State.
Whether a HUC vehicle, or a personal vehicle is used, the employee is responsible for any traffic
or parking citations the employee receives while operating such vehicle on HUC business.
Employees who drive a HUC vehicle home may use the vehicle only for HUC business purposes.
Employees who are members of the Hutchinson Fire Department or Rescue Squad may use a HUC
vehicle to travel to the fire station to respond to a call when the firefighter or rescue squad member
is on the job with HUC at the time of the call_ If the firefighter or rescue squad member is at HUC,
they must use a personal vehicle to respond to the call.
Air Travel and Rental Vehicles
It is recognized that air travel may be a necessary part of conducting business for HUC. In the
circumstances of air travel, the following rules shall apply:
• Commercial carriers shall be used.
• Tickets should be at "standard" or "coach" class.
• Travel to and from the airports shall follow the Business Related Vehicle Operation
section.
• Travel outside of the State must be approved by the employee's Pa..Fee.�o.F...(:)F Manager.
• Only employee's air travel expenses shall be prepaid, charged, or reimbursed at cost.
Rental vehicles may be used when traveling outside of the State. Reservations of a rental vehicle
shall be made at the same time air travel is arranged. Renting a vehicle must be approved by the
employee's DeetoF of Manager.
Overnight Stays, Meals and Entertainment Expenses
Hotel reservations shall be made prior to the employee leaving for out of town travel. The
following items shall apply to overnight stays:
• Hotel accommodations for the employee must be approved by the employee's i::.� fee.�of....of
Manager.
• In the event the employee is traveling on HUC business and experiences inclement
weather, to the extent that it is not safe to travel, or the employee is not able to travel due
to some circumstance that is beyond their control, then no prior approval for hotel
accommodations are necessary.
• Hotel rooms at convention or seminar sites are approved accommodations.
• Reimbursement is limited to employees and business related guests, and must be directly
related to business.
The following shall apply to expenses associated with meals:
• Meals shall be limited to a maximum of United States General Services Administration Per
Diam Rates by location. This rate is a maximum and not an allowance.
• Meal gratuity reimbursement by HUC shall not exceed 20% of the bill and is included in
the daily maximum meal allowance.
• Meal reimbursement is limited to employees.
• Expenses associated with alcoholic beverages shall not be reimbursed.
Expense Report
An expense report shall be filled out for all reimbursement requests for purchases using personal
funds. Unsupported expenses using personal funds shall not be reimbursed by HUC.
An expense report shall also be filled out for all company travel purchases. Unsupported expenses
on an HUC credit card shall be reimbursed to HUC by the employee.
The expense report must state the type of expense (meal, travel, hotel, etc.), the date and the
business purpose. Alcohol is not a reimbursable expense. It is the employee's responsibility to
obtain an itemized receipt. The expense report shall be approved by your DiFee�oF Manager; or
Supervisor before submitting to the Financial Manager.
NON-EXEMPT
COMPENSATION PLAN
Performance Evaluations
For all regular full-time employees, a performance appraisal or evaluation will be made on an
annual basis. An evaluation made by the employee's manager, or supervisor will be
submitted in writing to the employee and the General Manager. All evaluations will be
forwarded to the Human Resources for filing in the employee files.
Evaluations shall be based upon the performance of the individual in the position measured
against established job performance criteria. Such criteria may include level of knowledge,
skills, ability, quality of work, personal work traits, compliance with established HUC or
departmental rules and regulations or any other criteria that is indicative of performance.
The performance appraisal process is the application of performance standards to past
performance. In appraising an employee, these are the basic levels of performance:
5 — Outstanding Performer— Performance is exceptional in all areas and is recognizable as
being far superior to others.
4 — Exceeds Expectations — Results clearly exceed most positions requirements. Performance
is of high quality and is achieved on a consistent basis.
3 — Solid Performer — Competent and dependable level of performance. Meets performance
standards of the job.
2 — Needs Improvement — Performance is deficient in certain area(s). Improvement is
necessary.
1— Unsatisfactory — Results are generally unacceptable and require immediate improvement.
TRAVEL EXPENSES
Business Related Vehicle Operation
Travel within the State shall be by HUC vehicle if possible.
If a HUC vehicle is not available for in -State travel, or is not practical to use, then an employee
may seek approval from i::.k:ee.�(�*.....(:)F Manager to use a personal vehicle for transportation. The
following rules shall apply:
• The employee will be reimbursed for mileage at the current IRS mileage reimbursement
rate.
• HUC is not liable for damage to personally owned vehicles used for HUC business.
• HUC may request proof of insurance from employees who use personally owned vehicles
on HUC business.
• Travel to and from events should be by the most direct route possible.
• Employees are expected to return in a timely manner.
Travel outside of the State must be approved by the employee's P.i..Fee.�(�*.....(:)F Manager. If it is
appropriate to drive, the employee shall follow the same rules as travel within the State.
Whether a HUC vehicle, or a personal vehicle is used, the employee is responsible for any traffic
or parking citations the employee receives while operating such vehicle on HUC business.
Employees who drive a HUC vehicle home may use the vehicle only for HUC business purposes.
Employees who are members of the Hutchinson Fire Department or Rescue Squad may use a HUC
vehicle to travel to the fire station to respond to a call when the firefighter or rescue squad member
is on the job with HUC at the time of the call_ If the firefighter or rescue squad member is at HUC,
they must use a personal vehicle to respond to the call.
Air Travel and Rental Vehicles
It is recognized that air travel may be a necessary part of conducting business for HUC. In the
circumstances of air travel, the following rules shall apply:
• Commercial carriers shall be used.
• Tickets should be at "standard" or "coach" class.
• Travel to and from the airports shall follow the Business Related Vehicle Operation
section.
• Travel outside of the State must be approved by the employee's [)iFeeuoF..-oF Manager.
• Only employee's air travel expenses will be prepaid, charged, or reimbursed at cost.
Rental vehicles may be used when traveling outside of the State. Reservations of a rental vehicle
shall be made at the same time air travel is arranged. Renting a vehicle must be approved by the
employee's :Pk:ee.�of:....of: Manager.
Overnight Stays and Meals
Hotel reservations shall be made prior to the employee leaving for out of town travel. The
following items shall apply to overnight stays:
• Hotel accommodations for the employee must be approved by the employee's D�FeetoF of
Manager.
• In the event the employee is traveling on HUC business and experiences inclement
weather, to the extent that it is not safe to travel, or the employee is not able to travel due
to some circumstance that is beyond their control, then no prior approval for hotel
accommodations are necessary.
• Hotel rooms at convention or seminar sites are approved accommodations.
• Reimbursement is limited to employees and business related guests, and must be directly
related to business.
The following shall apply to expenses associated with meals:
• Meals shall be limited to a maximum of United States General Services Administration Per
Diam Rates by location. This rate is a maximum and not an allowance.
• Meal gratuity reimbursement by HUC shall not exceed 20% of the bill and is included in
the daily maximum meal allowance.
• Meal reimbursement is limited to employees.
• Expenses associated with alcoholic beverages will not be reimbursed.
Expense Report
An expense report shall be filled out for all reimbursement requests for purchases using personal
funds. Unsupported expenses using personal funds will not be reimbursed by HUC.
An expense report shall also be filled out for all company travel purchases. Unsupported expenses
on an HUC credit card shall be reimbursed to HUC by the employee.
The expense report must state the type of expense (meal, travel, hotel, etc.), the date and the
business purpose. Alcohol is not a reimbursable expense. It is the employee's responsibility to
obtain an itemized receipt. The expense report shall be approved by your D.i..Fee.�(:*. Manager; or
Supervisor before submitting to the Financial Manager.
HUTCHINSON UTILITIES COMMISSION
^I'�xP61Tti'°"
Board Action Form
Agenda Item: 2024 Annual Reliability Benchmarking Report
Presenter: Dave
Agenda Item Type:
Time Requested (Minutes): 5
New Business
Attachments: Yes
BACKGROUND/EXPLANATION OFAGENDA ITEM:
The American Public Power Association 2024 Annual Reliability Benchmarking Report.
This report provides Hutchinson Utilities with high -quality reliability benchmarking
information. This year's report includes our data in comparison to the 350 utilities that
provided and verified their data for 2024.
This report focuses on distribution system reliability across the country and is
customized to each utility that participates in the American Public Power
Association's eReliability Tracker service. APPA created the eReliability Tracker
Annual Report to assist utilities in their efforts to understand and analyze their
electric system.
Attachments:
2024 Reliability Benchmarking Report
2024 HUC outage Pie Chart
APPA Recognition for exceptional electric reliability in 2024
SAIDI, SAIFI, CAIDI Summary
BOARD ACTION REQUESTED:
None
Fiscal Impact: None
Included in current budget: Budget Change:
PROJECT SECTION:
Total Project Cost: Remaining Cost:
Hutchinson Utilities Commission
40 ANNUAL
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IIAB�1�1 11 ry
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American Public Power Association AMERICAN
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PCIA.1100-ER
ASSOCIATION
RESEARCH & DEVELOPMENT Powering Strong Communities
I. About This Report
This report focuses on distribution system reliability across the country and is customized to
each utility that participates in the American Public Power Association's eReliability Tracker
service. APPA created the eReliability Tracker Annual Report to assist utilities in their efforts to
understand and analyze their electric system. In 2012, APPA developed the eReliability Tracker
thanks to a grant from the Demonstration of Energy & Efficiency Developments (DEED)
program.
This report reflects data in the eReliability Tracker from January 1, 2024 to December 31, 2024.
This analysis might not properly reflect your utility's statistics if you do not have a full year of
data in the system. The report includes data recorded as of February 25, 2025.
Reliability reflects both historic and ongoing engineering investment decisions within a utility.
Proper use of reliability metrics ensures that a utility is performing its intended function and is
providing service in a consistent and effective manner.
While the primary use of reliability statistics is for self -evaluation, you can use these statistics
to compare your utility with similar utilities. However, differences such as electrical network
configuration, ambient environment, weather conditions, and number of customers served
typically limit most utility -to -utility comparisons. Due to the diverse range of utilities that use
the eReliability Tracker, this report endeavors to improve comparative analyses by grouping
utilities by size and region.
Since this report contains data for all utilities that use the eReliability Tracker, it is important to
consider how a particularly large or small utility can affect comparative benchmarks. To ease
the issues associated with comparability, each utility's reliability statistics are weighted based
on customer count when aggregated. This means that all utilities are equally weighted, and all
individual statistics are developed on a per customer basis.
The aggregate statistics in this report are calculated from the 350 utilities with verified 2024
outage data. Utilities that experienced no outages in 2024, or did not upload any data, will
have NULL, None, or "0" values in their report for utility -specific data and were not included in
the aggregate analysis. Also note that log -normal data with a z-scorell] greater than 3.25 may
be excluded if it significantly distorts the aggregate statistics.
[1 ]: A z-score indicates how much a data point differs from the mean. For instance, a z-score of 3.25 indicates that the data point
is three and one -quarter standard deviations from the mean. A z-score of 0 indicates that the data point is identical to the mean.
Utility Classifications
This report separates utilities into groups according to geographic region and the number of
customers served. Table 1 shows the range of customer counts for utilities that use the
eReliability Tracker by five distinct groups of approximately 107 utilities per group.
Your utility is in size class 3 and region 3.
Table 1. Customer count range per size class
.................................................................................................................................................................
.................................................................................................................................................................
Customer Count Range
Class 1
>0
.................................................................................................................................................................
Class 2
.................................................................................................................................................................
>1,527
Class 3
.................................................................................................................................................................
>3,582
Class 4
>7,526
...5............................................>1.452.8.........................................
...Class
Each utility is also grouped with all other participating utilities within their region. Figure 1
shows the number of utilities using the eReliability Tracker in each region and Figure 2 shows
the states and territories included in each region.
Figure 1. Number of utilities subscribed to the eReliability Tracker by region
140
120
V)
a)
+-+ 100
a-+
0
80
0
9? 60
.B
E
40
Z
20
5
Regions
Figure 2. Regions
48
AMERICAN GUAM NORTHERN PUERTO U.S. VIRGIN
SAMOA MARIANA RICO ISLANDS
ISLANDS
II. IEEE Statistics
When it comes to reliability, the industry standard metrics are defined in the Institute for
Electrical and Electronics Engineers' Guide for Electric Power Distribution Reliability Indices, or
IEEE 1366 guidelines. For each utility, the eReliability Tracker performs IEEE 1366 calculations
for System Average Interruption Duration Index (SAIDI), System Average Interruption
Frequency Index (SAIFI), Customer Average Interruption Duration Index (CAIDI), Momentary
Average Interruption Frequency Index (MAIFI), and Average Service Availability Index (ASAI).
It is important to note how major events (MEs) are calculated and used in this report. An
example of an ME includes severe weather, such as a tornado or hurricane, that leads to
unusually long outages in comparison to your distribution system's typical outage. This report
uses the APPA ME threshold, which is based directly on the SAIDI for specific outage events,
rather than a daily SAIDI. The APPA ME threshold allows a utility to remove outages that
exceed the IEEE 2.5 beta threshold for outage events, which considers up to 10 years of the
utility's outage history. In the eReliability Tracker, if a utility does not have at least 36 outage
events prior to the year being analyzed, then no threshold is calculated. If this is the case for
your utility, then you will have a NULL value in the following field and the calculations without
MEs in the SAIDI, SAIFI, CAIDI, and ASAI sections of this report will be the same as the
calculations with MEs for your utility. More outage history will provide a better threshold for
your utility.
Your utility's APPA major event threshold is 56.65 minutes.
For each of the reliability indices, this report displays your utility's metrics alongside the mean
values for all utilities using the eReliability Tracker and within the same class and region as
your utility. The first table within each of the following subsections allows you to better
understand the performance of your electric system relative to other utilities nationwide and
to those within your same region or size class. The second table breaks down the national
data into quartile ranges, a minimum value, and a maximum value.
All indices, except MAIFI, are calculated for outages with and without MEs. Furthermore, the
tables show indices for scheduled and unscheduled outages. Note that scheduled and
unscheduled calculations include MEs. Also note that wherever MEs are excluded, the
exclusion is based on the APPA ME threshold for your system.
II.1. System Average Interruption Duration Index
SAIDI is the average duration (in minutes) of an interruption per customer served by the utility
during a specific time frame.
Since SAIDI is a sustained interruption index, only outages lasting longer than five minutes
are included in the calculations. SAIDI is calculated by dividing the sum of all customer
minutes of interruption[21 within the specified time frame by the average number of
customers served during that period. For example, a utility with 100 customer minutes of
interruption and 100 customers would have a SAIDI of 1.
Note that in the tables below, scheduled and unscheduled calculations include MEs. Also note
that wherever MEs are excluded, the exclusion is based on the APPA ME threshold for your
system.
Table 2. Average SAIDI with and without MEs
In minutes
All No MEsUnscheduled Scheduled
Your utility 41.69
............................................................................................................................................................................................................................................................................................................................................................................................................................
41.69
41.69
NULL
Utilities that use the eReliability Tracker
120.3
54.49
113.49
13.19
............................................................................................................................................................................................................................................................................................................................................................................................................................
Utilities in your region
50.0
32.24
48.83
3.0
..size
...class
...i.n......... your
Utilities 94.56
43.76
90.01
8.41
Table 3. Summary SAIDI data from the eReliability Tracker
In minutes
All ..............�...No...MEs
..L.Unscheduled
....Scheduled
Minimum
..................................................................................................................................................................................................................................................................................................
0.08
0.08
0.08
<0.01
First Quartile
19.39
11.07
18.77
0.19
..................................................................................................................................................................................................................................................................................................
Median
44.37
26.79
40.95
1.24
..................................................................................................................................................................................................................................................................................................
Third Quartile
131.4
55.66
127.24
5.03
Maximum
1,639.92
776.98
1,634.25
629.54
[2]: Customer minutes of interruption is calculated by multiplying total customers interrupted and total minutes of interruption.
Figure 3. Average SAIDI by region
350
4-' 300
P 250
200
lfY
150
100
cU
.� 50
5
Regions
II.2. System Average Interruption Frequency Index
SAIFI is the average instances a customer on the utility system will experience a sustained
interruption during a specific time frame.
Since SAIFI is a sustained interruption index, only outages lasting longer than five minutes are
included in the calculations. SAIFI is calculated by dividing the total number of customers that
experienced sustained interruptions by the average number of customers served during that
period. For example, a utility with 150 customer interruptions and 200 customers would have
a SAIFI of 0.75.
Note that in the tables below, scheduled and unscheduled calculations include MEs. Also note
that wherever MEs are excluded, the exclusion is based on the APPA ME threshold for your
system.
Table 4. Average SAIFI with and without MEs
In interruptions
.................................................................................................................................................................................................................................................................................................................................................................
All
No MEs
Unscheduled
Scheduled
......................................................................................................................................................................................................................................................................................................................................................................................................................
Your utility
......................................................................................................................................................................................................................................................................................................................................................................................................................
0.82
0.82
0.82
NULL
Utilities that use the eReliability Tracker
0.78
0.54
0.75
0.06
......................................................................................................................................................................................................................................................................................................................................................................................................................
Utilities in your region
0.52
0.4
0.51
0.03
..................................................................................0.
..size
...i.n......... your
...class
Utilities
78......................0.
52...................................................0.76
. 76004
Table 5. Summary SAIFI data from the eReliability Tracker
In interruptions
All
..........No...MEs
.L.Unscheduled ....................................................
Scheduled
Minimum
...................................................................................................................................................................................................................................................................................
<0.01
<0.01
<0.01
<0.01
First Quartile
0.21
0.14
0.19
<0.01
...................................................................................................................................................................................................................................................................................
Median
0.54
0.36
0.53
0.01
...................................................................................................................................................................................................................................................................................
Third Quartile
1.16
0.77
1.1
0.04
Maximum
3.63
2.43
3.63
2.32
Figure 4. Average SAM by region
1.2
Ln
0
1.0
0.8
0.0
5
Regions
II.3. Customer Average Interruption Duration Index
CAIDI is the average duration (in minutes) of an interruption experienced by customers during a
specific time frame.
Since CAIDI is a sustained interruption index, only outages lasting longer than five minutes
are included in the calculations. CAIDI is calculated by dividing the sum of all customer
minutes of interruption by the number of customers that experienced one or more
interruptions during that period. This metric reflects the average customer experience
(minutes of duration) during an outage.
Note that in the tables below, scheduled and unscheduled calculations include MEs. Also note
that wherever MEs are excluded, the exclusion is based on the APPA ME threshold for your
system.
Table 6. Average CAIDI with and without MEs
In minutes
All
No MEs
Unscheduled
Scheduled
..................................................................................................................................................................................................................................................................................................................................................................................................................................
Your utility
..................................................................................................................................................................................................................................................................................................................................................................................................................................
50.78
50.78.7
LL
Utilities that use the eReliability Tracker
135.22
92.4
138.62
153.96
..................................................................................................................................................................................................................................................................................................................................................................................................................................
Utilities in your region
95.65
83.74
95.41
105.79
..size
...i.n......... your
...class
Utilities
142.62
93.1
4O.c
.85
Table 7. Summary CAIDI data from the eReliability Tracker
In minutes
ALL .................No...MEs
.L.Unscheduled
..................................................
Scheduled
Minimum
..................................................................................................................................................................................................................................................................................................
11.21
11.21
10.52
7.82
First Quartile
62.85
51.38
62.41
61.8
..................................................................................................................................................................................................................................................................................................
Median
93.56
81.55
93.94
95.16
..................................................................................................................................................................................................................................................................................................
Third Quartile
143.73
110.8
144.19
162.66
Maximum
1,923.68
402.94
2,012.24
1,899.69
Figure S. Average CAIDI by region
yr 200
V
4�
P 150
U 100
Cif
50
Regions
II.4. Momentary Average Interruption Frequency Index
MAIFI is the average number of momentary interruptions a utility customer will experience during a
specific time frame.
In this report, an outage with a duration of five minutes or less is classified as momentary.
MAIFI is calculated by dividing the total number of customers that experienced momentary
interruptions by the total number of customers served by the utility. For example, a utility with
20 momentary customer interruptions and 100 customers would have a MAIFI of 0.20.
Momentary interruptions can be more difficult to track and utilities without an automated
outage management system might not log these interruptions; therefore, some utilities have
a MAIFI of zero.
Table 8. Average MAIFI
In interruptions
...................................................................................................................................................................................................................................................
All
...................................................................................................................................................................................................................................................
Your utility
...................................................................................................................................................................................................................................................
NULL
Utilities that use the eReliability Tracker
0.45
...................................................................................................................................................................................................................................................
Utilities in your region
0.7
........................................................................................0..35.
..size
...class
...i.n......... your
Utilities
Table 9. Summary MAIFI data from the eReliability Tracker
In interruptions
All
..........................................................................................................
Minimum
..........................................................................................................
<0.01
First Quartile
<0.01
..........................................................................................................
Median
0.06
..........................................................................................................
Third Quartile
....................................5..0.
0.53
Maxi.m.u.m
Figure 6. Average MAIR by region
0.7
0.6
0.5
0.4
0.3
(U) 0.2
0
0.1
0.0
5
Regions
U.S. Average Service Availability Index
ASAI is the percentage of time the sub -transmission and distribution systems are available to serve
customers during a specific time frame.
This load -based index represents the percentage availability of electric service to customers
within the period analyzed. It is calculated by dividing the total hours in which service is
available to customers by the total hours that service is demanded by the customers. For
example, an ASAI of 99.99% means that electric service was available for 99.99% of the time
during the given period. Note that the higher your ASAI value, the better the performance.
In the tables below, scheduled and unscheduled calculations include MEs. Also note that
wherever MEs are excluded, the exclusion is based on the APPA ME threshold for your system.
Table 10. Average ASAI with and without MEs
In percentage
........................................................................................................................................................................................................................................................................................................................................................................................................................................
All
No MEs
Unscheduled
Scheduled
........................................................................................................................................................................................................................................................................................................................................................................................................................................
Your utility 99.992
........................................................................................................................................................................................................................................................................................................................................................................................................................................
99.992
99.992
NULL
Utilities that use the eReliability Tracker
99.9775
99.9898
99.9787
99.9976
........................................................................................................................................................................................................................................................................................................................................................................................................................................
Utilities in your region
99.9905
99.9939
99.9907
99.9994
..size
...i.n......... your
...class
Utilities 99.982
99.9829
99.9983
Table 11. Summary ASAI data from the eReliability Tracker
In percentage
................................................................................................................................................................................................................................................................................................
All
No MEs
Unscheduled
Scheduled
................................................................................................................................................................................................................................................................................................
Maximum
................................................................................................................................................................................................................................................................................................
99.9999
99.9999
99.9999
99.9999
First Quartile
99.9963
99.9978
99.9964
99.9999
................................................................................................................................................................................................................................................................................................
Median
99.9916
99.9949
99.9922
99.9997
................................................................................................................................................................................................................................................................................................
Third Quartile
.0.
99.9755
99.9894
99.9765
99.999
i n..
Minimum
99.6888
99.86
99.6899
99.8856
Figure 7. Average ASAI by region
100.000
tly 99.975
99.950
cll
99.925
OL
Q 99.900
in
< 99.375
cu 99.350
99.325
99.300
5
IRegionis
II.6. Energy Information Administration Form 861 Data
Form EIA-861 collects annual information on electric power industry participants involved in the
generation, transmission, distribution, and sale of electric energy in the United States and its
territories.
In 2014, Energy Information Administration (EIA) began publishing reliability statistics in Form
EIA-861; therefore, APPA included these statistics in this report for informational purposes.
Please note that the following data includes 174 investor -owned, 467 rural cooperative, and
327 public power utilities that were large enough to be required to fill out the full EIA-861
form. The statistics do not include data from utilities that complete the EIA 861-S form, which
smaller entities complete. Note that the 327 participating public power utilities include
entities classified by EIA as municipal, political subdivision, and state. In addition, since the
collection and release of EIA form data lags by a year, the data is based on 2023 data that was
published October 10, 2024. Therefore, we suggest you only use the aggregate statistics
contained herein as an informational tool for further comparison of reliability statistics.
In Form EIA-861, an entity provides SAIDI and SAIFI including and excluding ME days in
accordance with the IEEE 1366-2003 or IEEE 1366-2012 standard.
Although EIA collected other reliability -related data, the tables below only include SAIDI and
SAIFI data including and excluding ME days. You can download the full set of data at:
www.eia.gov/electricity/data/eia861 /.
Table 12. Your utility's SAIDI and SAIFI with and without IEEE ME days
....................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................
SAIDI with IEEE ME SAIDI without IEEE SAIFI with IEEE ME days SAIFI without IEEE ME
days (minutes) ME days (minutes) (interruptions) days (interruptions)
Table 13. Summary SAIDI data from Form EIA-861, 2023
In minutes
.............................................................................................................................................................................
.............................................................................................................................................................................
All
No MEs
Average
.............................................................................................................................................................................
376.90
149.41
Minimum
0.20
0
.............................................................................................................................................................................
First Quartile
.............................................................................................................................................................................
80.88
51.59
Median
178.01
101.18
.............................................................................................................................................................................
Third Quartile
392.12
175.32
Maxi.m.u.m........................1..0.82.0.00....2.475..0.9.
Table 14. Summary SAIFI data from Form EIA-861, 2023
In interruptions
....................................................................................................................................................
....................................................................................................................................................
All
No MEs
Average
....................................................................................................................................................
1.71
1.26
Minimum
0.01
0
....................................................................................................................................................
First Quartile
0.82
0.60
Median
1.30
0.99
....................................................................................................................................................
Third Quartile
2.14
1.54
Maxi..m.u.m1117.38
16.92
III. Outage Causes
Equipment failure, extreme weather events, wildlife, and vegetation are some of the most
common causes of electric system outages. The following pie chart shows the percentages of
the primary causes of outages for all utilities using the eReliability Tracker in 2024.
wildllife
Scheduled
Figure 8. Primary causes of outages in 2024
neat
Utility Human Error
Power Supply
Pubic
am
Certain factors, such as regional weather and animal/vegetation patterns, can make some
causes more prevalent for a specific group of utilities. The following section includes graphs
depicting common causes of outages for your utility, all utilities in your region, and all utilities
using the eReliability Tracker.
Charts containing aggregate information are customer -weighted to account for differences in
utility size for a better analytical comparison. For example, a particularly large utility may have
a large number of outages compared to a small utility. To avoid skewing the data toward large
utilities, the number of cause occurrences is divided by customer size to account for the
differences. In Figures 9 to 14, the data represent the number of occurrences for each group
of 1,000 customers. A customer -weighted occurrence rate of "1" means an average of one
outage from that cause occurred per 1,000 customers in 2024.
Note that the sustained outage cause analysis is more comprehensive than the momentary
outage cause analysis due to a larger and more robust sample size for sustained outages.
Regardless, tracking both sustained and momentary outages helps utilities understand and
reduce outages. To successfully use the outage information tracked by your utility, it is
imperative to classify and record outages in detail. The more information provided per
outage, the more conclusive and practical your analyses will be.
III.1. Sustained Outage Causes
In general, sustained outages are the most commonly tracked outage type. In analyses of
sustained outages, utilities tend to exclude scheduled outages, partial power, customer -
related problems, and qualifying major events from their reliability indices calculations. While
this is a valid method for reporting, these outages should be included for internal review to
make utility -level decisions. In this section, we evaluate common causes of sustained outages
for your utility, corresponding region, and for all utilities that use the eReliability Tracker. It is
important to note that sustained outages are classified in this report as outages that last
longer than five minutes, as defined by IEEE 1366.
Figure 9. Top five causes of sustained outages for all utilities that use the eReliability Tracker
2.5
a
0 2.0
1-4
2 1.5
V
V
G
1.0
u
u
O 0.5
0.0
Non -Payment Tree Equipment Squirrel Utility Maintenance and Repaiins
Outage Cause Types
Figure 10. Top five causes of sustained outages for your utility[31
0.40
0.35
O
O 0.30
r�l
L
�Q) 0.25
0.20
0.15
L
0.10
0.05
0.00
Outage Cause Types
[3]: The number of occurrences for each cause is divided by the utility's customer count (in thousands) to create an occurrence
rate that can be compared across different utility sizes.
Figure 11. Top five causes of sustained outages in your region
20.40
20.0
S17.5
10.0
7.5
:3
U
U 5.0
0 270
2.5 .................
1.23
0.0 Ncr,-Payment Utility Maintenance and Repairs 11 Squirrel Weather Tree
Outage Cause Types
III.2. Momentary Outage Causes
The ability to track momentary outages can be difficult or unavailable on some systems, but
due to the hazard they pose for electronic equipment, it is important to track and analyze the
causes of momentary outages. This section evaluates the common causes of momentary
outages for your utility, region, and size class as well as common causes for all utilities that
use the eReliability Tracker. Please note that only outages lasting less than five minutes are
classified as momentary, as defined by IEEE 1366. In Figures 12-14, for each utility, the
number of occurrences for each cause is divided by that utility's customer count (in
thousands) to create an occurrence rate that can be compared across different utility sizes.
Figure 12. Top five causes of momentary outages for all utilities that use the eReliability
Tracker
0.8
(j 0.7
0
rWl 0.6
L
0.5
0.4
0.3
u 0.2
0.1
0.0
Equipment Replacement Other - Vegetation Non -Payment Utility Maintenance and Repairs Unknown
Outage Cause Types
Figure 13. Top five causes of momentary outages for your utility
0.04
O
a
0
v-A 0.02
v
a
'7 0.00 0.000 0.000 0.000 0.000 0.000
V
G
4J
—0.02
U
u
O
—0.04
None None None None None
Outage Cause Types
Figure 14. Top five causes of momentary outages in your region
O
6
(U
a� 5
(U
U 4
C
aj
U
u 2
0
8.45
JJJJJJJJJJJJJJJJJJJ
�ijji 11111
Nor -Payment Unknown Heat St,�rm Manufacturing Defect
Outage Cause Types
Thank you for your active participation in the eReliability Tracker service. We hope this report
is useful to your utility in analyzing your system. If you have any questions regarding the
material provided in this report, please contact:
APPA's Reliability Team
Paul Zummo
Ji Yoon Lee
Matthew Atienza
Gregory Obenchain
ReliabilLtyu lic o eror
For more information on reliability, visit tt :// u lic o eror /relic ili -tracking.
Copyright 2025 by the American Public Power Association. All rights reserved.
Causes Pie Chart
Hutchinson Utilities
Commission
Start Date: Substation:
01 /01 /2024 ® -----
End Date: Circuit:
12/31 /2024 ® -----
Includes outages that started on the End Date.
Report on Outage:
Top-level Cause
Count
v y Duration
Customers Interrupted
Equipment Worn
9%
Squirre
9%
Other
Electrical Failure Manufacturing Defect
9% 9%
Vehicle Accident
9%
id
nknown
9%
v
v
Outage Cause
Underground
Unknown
Manufacturing Defect
Vehicle Accident
Electrical Failure
Squirrel
Equipment Worn Out
"Other" causes
Weather
Wind
Total
Count
3
1
1
1
1
1
1
SAIDI (minutes) The average durration of an interruption per customer
H U C 41.69
Utilities in our Region 50
SAIFI (number of interruptions) The average instances a cutmomer on the Utility system will experience a sustained interruption
H U C 0.82
Utilities in our Region 0.52
CAIDI (minutes) The average duration of an interuption experienced by customers
H U C 50.78
Utilities in our Region 95.65
225 Michigan Street SE
TT Hutchinson, MN 55350-1905
Hutchinson 320-587-4746 1 Fax 320-587-4721
V
�m tilities www.hutchinsonutilities.com
�Commission
Putting All of Our Energy into Serving You
HUTCHINSON UTILITIES COMMISSION
RECOGNIZED
FOR RELIABLE ELECTRIC SERVICE TO THE COMMUNITY
Hutchinson MN 2025 — Hutchinson Utilities Commission has received national recognition for achieving
exceptional electric reliability in 2024. The recognition comes from the American Public Power
Association (APPA), a trade group that represents more than 2,000 not -for -profit, community -owned
electric utilities.
APPA helps electric utilities track power outage and restoration data through its subscription -based
eReliability Tracker service. Once per year, APPA's Reliability Team compares this data to national
statistics tracked by the U.S. Energy Information Administration for all types of electric utilities.
"Year after year, data consistently demonstrate public power utilities provide highly reliable service." said
APPA Director of Research and Development Paul Zummo. "The utilities recognized here are truly elite
when it comes to keeping the lights on. Their communities should be proud of the hard work and
dedication of their local power providers as they earn this truly deserved recognition."
Nationwide, the average public power customer has their lights out for less than half the amount of time
that customers of other types of utilities do.
"We are proud to receive this recognition. It is a testament to the hard work of all our staff to ensure that
we keep Hutchinson powered," said Jeremy Carter, General Manager at Hutchinson Utilities
Commission.
For more information on Hutchinson Utilities Commission and its commitment to reliability, visit
://www.tiL'tcliitiSorlutilities.c01TI/
HUTCHINSON UTILITIES COMMISSION
^I'�xP61Tti'°"
Board Action Form
Agenda Item: 2024 Safety Award of Excellence
Presenter: Dave
Agenda Item Type:
Time Requested (Minutes): 5
New Business
Attachments: Yes
BACKGROUND/EXPLANATION OFAGENDA ITEM:
Hutchinson Utilities Commission has earned the American Public Power Association's
Safety Award of Excellence for safe operating practices in 2024.
Hutchinson Utilities received the Diamond (Top) designation.
Attachments:
Safety Award Press Release
BOARD ACTION REQUESTED:
None
Fiscal Impact:
Included in current budget: No Budget Change: No
PROJECT SECTION:
Total Project Cost: Remaining Cost:
CHINSNy 225 Michigan Street SE
Hutchinson Hutchinson, MN 55350-1905
Utilities 320-587-4746 1 Fax 320-587-4721
www.hutchinsonutilities.com
�r�iit�es Commission
Putting All of Our Energy into Serving You
HUTCHINSON UTILITIES COMMISSION HONORED WITH NATIONAL AWARD
FOR OUTSTANDING SAFETY PRACTICES
WASHINGTON, D.C., April 1, 2025 — Hutchinson Utilities Commission has earned the
American Public Power Association's Safety Award of Excellence for safe operating
practices in 2024. The utility earned Diamond award in the category for utilities with
60,000 to 109,000 worker -hours of annual worker exposure.
More than 200 utilities entered the annual Safety Awards for 2024. The entrants are
placed in accordance with their number of worker -hours and ranked based on the most
incident -free records and overall state of their safety programs and culture during 2024.
The incidence rate is based on the number of work -related reportable injuries or
illnesses and the number of worker -hours during 2024, as defined by the Occupational
Safety and Health Administration (OSHA).
"Hutchinson Utilities Commission is proud of our safety culture. said Jeremy Carter,
General Manager of Hutchinson Utilities Commission ". This award is a testament to
the safety culture we have built and the hard work that goes into ensuring that our team
members have a safe work environment."
"Harnessing electricity to keep our communities powered is vital work that can be
dangerous, even deadly, if the proper attention isn't paid to tried-and-true safety
practices," said Jon Beasley, Chair of APPA's Safety Committee and Vice -President of
Electric Cities of GA. "This award honors utilities that hold fast to these practices and —
in doing so — put the safety of their personnel and their customers above all else."
APPA has conducted the Safety Awards annually for more than sixty-six years. APPA is
the voice of not -for -profit, community -owned utilities that power 2,000 towns and cities
nationwide.
HUTCHINSON UTILITIES COMMISSION
^I'xP61Tti'°"
Board Action Form
Agenda Item: Approve Requisition 010216 - Renegade Professional Services
Presenter: Jeremy Carter
Agenda Item Type:
Time Requested (Minutes): 5
New Business
Attachments: Yes
BACKGROUND/EXPLANATION OFAGENDA ITEM:
Renegade Energy Advisors (REA) has provided a proposal to assist HUC and HCP in
meeting annual Federal and State regulatory compliance items for 2025.
Annually under the purview of the Federal Department of Transportations Office of
Pipeline and Hazardous Materials Safety Administration (PHMSA) HUC and HCP are
required to assess and delineate their HCA & MCA areas, perform a class location
assessment, and update imagery on an annual basis.
In addition, a constant review, update, and refinement of procedure manuals and
programs are needed to stay in compliance with changing regulations.
HUC has budgeted for the portion of costs associated with HUC's transmission line.
HCP will be responsible for their portion of the costs in order to stay in compliance with
the transmission line they now currently own.
The total requisition costs are $129,895, of which HCP will be responsible for $34,485.
This leaves a net fiscal impact to HUC of $95,410
BOARD ACTION REQUESTED:
Approve Requisition 010216
Fiscal Impact: $95,410
Included in current budget: Yes Budget Change:
PROJECT SECTION:
Total Project Cost: Remaining Cost:
HUTCHINSON
UTILITIES
PURCHASE REQUISITION
HUTCHINSON UTILITIES COMMISSION
225 MICHIGAN ST SE
HUTCHINSON, MN 55350
Phone:320-587-4746 Fax:320-587-4721
RENEGADE ENERGY ADVISORS LLC.
448 N CEDAR BLUFF ROAD SUITE 183
KNOXVILLE, TN 37923
Note
Description:
Date
Requisition No.
04/16/2025
010216
Required by:
04/30/2025
Requested by:
jcarter
Item
No.
part No.
Description
Qty
Unit
Due Date
Unit Price
Ext. Amount
RENEGADE PROFESSIONAL SERVICES - 2025
- MFG. PART:
1
1.00
$95,410.000
$95,410.00
HCP RENEGADE PROFESSIONAL SERVICES -
25- MFG.
2
PART:
1.00
$34,485.000
$34,485.00
Total: 129,895.00
Date Printed: 04/16/2025 Requisitioned By: jcarter Page: 1/1
RENEGADE
ENERGY
REA ADVISORS,LLC
December 17th, 2024
Jeremy Carter, General Manager
Hutchinson Utilities Commission
225 Michigan St SE
Hutchinson, MN 55350-1905
mom
Renegade Energy Advisors, LLC ("REA") is pleased to present Mutchinson Itilities Commission ("M#C") with this
proposal assist with the annual regulatory compliance items to satisfy PHMSA and the state of Minnesota for both
H UC assets (Task 1 ) and Heartland Corn Products ("HCP) assets (Task 2).
SCOF:1II:.:.:1 &1::° WURK
F «� s k 1 HlUtChhnsoin Utilili.e.s Reg..g.�.a.to.ry Eye ire i r e m e n t s
......................................................................................................................... ... . ..... ..... ............. ..... ......... ... . . ............................ . .............
Item 1 — HCA/IVICA & Class Location Assessment
Deliverables:
• All GIS shapefiles generated during the assessment,
• PDF maps and figures (if requested),
• Data spreadsheets (if requested),
• Final report, including methodology and total mileage of class locations, HCAs & MCAs.
Assumptions:
• This assessment will be completed via remote geospatial analyses; no field verifications will be performed. REA
assumes that HUC personnel will complete field verification activities, if deemed necessary.
• HUC will incur the cost to acquire updated imagery. In 2024, HUC was able to take advantage of the NAIP
satellite passing through Minnesota, which provides very low-cost imagery to the public. Unfortunately, NAIP only
passes through Minnesota every 3 years, and class location studies require yearly updated imagery. HUC will
need to purchase imagery in the years NAIP imagery is unavailable. REA proposes to locate an appropriate
imagery vendor, acquire imagery for H UC's needs, and pass -through these costs. HUC will need —100 sq km of
imagery, and costs should range between $18.00-$22.00 per sq km. REA estimates it will cost between $25,000-
$31,000 for 2025 imagery.
Item 2 — Procedural IManual Reviews & Updates
REA proposes to provide the required annual review of the PHMSA-regulated transmission and distribution
procedural manuals. REA will review manuals to meet current PHMSA regulations found in 49 CFR Parts 191 and
192 and applicable requirements per the State of Minnesota. Status meetings with key HUC personnel are
recommended at least once/month of the project duration.
FOR WOR Fo =-
1711110-4=1
• Final Manuals in PDF compatible file incorporating all final approved changes and rectified comments.
• Gas IMP Risk Matrix in Excel format
Manuals included in the review:
cPhone (304) 993-3034 448 N. Cedar Bluff Road
d), 0 www.RenegadeEnergyAdvisors.com 0 Suite 183
Knoxville, TN 37923
RENEGADE
ENERGY
REA ADVISORS,LLC
• Emergency Response Plan (ERP)
• Public Awareness (PA) Manual
Assumptions:
Final procedural documents will be transmitted electronically in Word and PDF compatible formats for record
retention and future modification.
Currently, the status of new, final Federal rules that could affect HUC's assets is unknown. If new rules are issue�
that could affect the above referenced procedural manuals, REA will provide an updated scope.
Item 3 — Risk Assessment Analysis
REA's team will use a quantitative risk model to assess the risk of HUC's one high consequence area (HCA) and one
moderate consequence area (MCA). Existing construction and operation data will be used, as available. If data is not
available, conservative estimates per PHMSA guidelines will be used to establish both a likelihood and consequence for
each consequence segment. Bi-weekly meetings with appropriate HUC staff are proposed.
Deliverables:
• Excel risk assessment sheet of each consequence area
• Final report of findings.
F «� s k 2 Heartland ("orin Pirodi.lc.t.s R.e.(� U I c3 to ir y g.j�j ir e r"n e in t s
.................................................................................................. .& ..................................................... ... .... ...... ..... �1 ............................ ..... 1� .. .. .......................................
Item 1 — HCA/IVICA & Class Location Assessment
WO VIA-
will categorize HUC's pipeline by class and delineate all HCA and MCA areas.
Deliverables:
• All CIS shapefiles generated during the assessment,
• PDF maps and figures (if requested),
• Data spreadsheets (if requested),
• Final report, including methodology and total mileage of class locations, HCAs & MCAs.
Assumptions:
• This assessment will be completed via remote geospatial analyses; no field verifications will be performed. REA
assumes that HUC personnel will complete field verification activities, if deemed necessary.
• The imagery acquired for Task 1/Item 1 will also be used for Task 2/Item 1.
Item 2 — Procedural IManuall Reviews & Updates
REA proposes to provide the required annual review of the PHMSA-regulated transmission and distribution
procedural manuals. REA will review manuals to meet current PHMSA regulations found in 49 CFR Parts 191 and
192 and applicable requirements per the State of Minnesota. Status meetings with key HUC personnel are
recommended at least once/month of the project duration.
BMT 10=3 101
liraft Manuals irr"Tord compatible files
r:inal Manuals in PDF compatible file incorporating all final approved changes and rectified comments.
0 Gas IMP Risk Matrix in Excel format
Manuals included in the review:
• Operations & Maintenance Manual
• Integrity Management Program Manual
• Emergency Response Plan
• Public Awareness Manual
Assumptions:
• Final procedural documents will be transmitted electronically in Word and PDF compatible formats for record
retention and future modification.
• Currently, the status of new, final Federal rules that could affect HUC's assets is unknown. If new rules are issue�
that could affect the above referenced procedural manuals, REA will provide an updated scope.
cPhone (304) 993-3034 448 N. Cedar Bluff Road
d), www.RenegadeEnergyAdvisors.com 0 Suite 183
Knoxville, TN 37923
RENEGADE
REA ENERGY
ADVISORS,LLC
Item 3 — Risk Assessment Analysis
REA's team will use a quantitative risk model to assess the risk of HCP's one high consequence area (HCA) and one
moderate consequence area (MCA). Existing construction and operation data will be used, as available. If data is not
available, conservative estimates per PHMSA guidelines will be used to establish both a likelihood and consequence for
each consequence segment. Bi-weekly meetings with appropriate HUC/HCP staff are proposed.
Deliverables:
• Excel risk assessment sheet of each consequence area.
• Final report of findings.
P IR () J C °f„° °f„°III III.. II II' S
HCA-MCA & Class Location assessmentcompleted 0
Item 2 — Proposed updates to the regulatory manuals will be completed by December 31st, 2025.
Item 3 — Executed risk assessments will be completed by December
HCA-MCA & Class Location assessmentcompleted 0
Item 2 — Proposed updates to the regulatory manuals will be completed by December 31st, 2025.
Item 3 — Executed risk assessment will be completed by December
COS I
.......................................................................................................................................................................................................................................................................................................................................................................................................................................................................................
HEARTLAND CORN PRODUCTS REGULATORY REQUIREMENTS
ITEM DESCRIPTION
AMOUNT
Item 1 — HCA/MCA & Class Location Assessment
....................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................
.
2025 Geospatial Analysis
...............................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................
$5,95
...................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................
Item 1 — Total Cost
$5,985
Item 2 — Procedural Manual Reviews & Updates
......................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................
Transmission Manual U.dates
.......................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................
$17,100
t — Total of
$17,100
...................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................
Item 3 — Risk Assessment AnalYsis
.......................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................
Risk Assessment — 1 HCA
$5,700
...............................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................
Risk Assessment — 1 MCA
$5,700
...............................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................
Item 3 — Total of
$11,400
...............................................................................................................................................................................................................................................................
.................................................................................................................................................................................................................................................................................................................................................................................................................................................��..............................................................................................................................................................................................................................
Task 1_ HCP Total
:..................................................
34 485....................................................
$ ,
cd),Phone )304) 993-3034 448 N. Cedar Bluff Road
� �'� www.RenegadeEnergyAdvisors.com 0 Suite 183
Knoxville, TN 37923
RENEGADE
ENERGY
REA ADVISORS,LLC
MI M-1, 11 11 111 i III III
MML*JM1l#§MMM1 � , M mmelffilammum is I M
Sincerely,
Brandi P. Wolfe
Renegade Energy Advisors, CEO
cPhone (304) 993-3034 448 N. Cedar Bluff Road
d), www.RenegadeEnergyAdvisors.com 0 Suite 183
Knoxville, TN 37923
HUTCHINSON UTILITIES COMMISSION
Board Action Form
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Agenda Item: Approval of Natural Gas Facilities Maintenance Agreement - City of Fairfax
Presenter: Jeremy Carter
Agenda Item Type:
Time Requested (Minutes): 2
New Business
Attachments: Yes
BACKGROUND/EXPLANATION OF AGENDA ITEM:
The City of Fairfax has requested that the Natural Gas Division of Hutchinson Utilities
continue performing the maintenance on their natural gas transmission/distribution
interconnect and line control facilities serving all customers to the east on Highway 19
and the Cities of Fairfax and Gibbon effective April 1, 2025.
Hutchison Utilities must present proof of PHMSA Drug and Alcohol Testing as well as
pertinent Operator Qualifications for all Natural Gas Division staff performing work on the
City of Fairfax facilities.
The term for this Agreement is one year.
BOARD ACTION REQUESTED:
Approval of Maintenance Agreement
Fiscal Impact: $5,000 - $10,000 Estimated
Included in current budget: No Budget Change: No
PROJECT SECTION:
Total Project Cost: 0.00 Remaining Cost: 0.00
HUTCHINSON UTILITIES COMMISSION
MAINTENANCE AGREEMENT
NATURAL GAS FACILITIES
City of Fairfax
03/19/2025
This document sets forth the terms and conditions of service for operation and maintenance of
the City of Fairfax's natural gas transmission/distribution metering, regulating, odorizing, water
bath heater and line control facilities provided to the City of Fairfax by Hutchinson Utilities
Commission.
NATURAL GAS FACILITIES MAINTENANCE AGREEMENT
THIS NATURAL GAS FACILITIES MAINTENANCE AGREEMENT ("Agreement") is
made and entered into on this 26th day of March, 2025, by and between the City of Fairfax
("Owner") with offices located at 18 lst Ave SE, Fairfax, Minnesota, 55332 and Hutchinson
Utilities Commission ("Operator") a Minnesota municipal utility located at 225 Michigan St. SE,
Hutchinson, Minnesota, 55350. Owner and Operator shall hereinafter sometimes be referred to
separately as "Party" or jointly as "Parties."
WITNES SETH:
WHEREAS, Owner has constructed or is constructing the Natural Gas Facilities (as
hereinafter defined);
WHEREAS, Owner desires to retain Operator to Maintain the Natural Gas Facilities on
behalf of Owner, and Operator is willing to provide said services on the terms and conditions set
forth herein.
NOW, THEREFORE, in consideration of the premises, mutual covenants, conditions and
agreements herein contained the parties hereto, intending to be legally bound, hereby agree as
follows:
ARTICLE I: DEFINED TERMS
Section 1.1 Definitions.
The defined terms used in this Agreement shall, unless the context otherwise requires, have the
meanings specified in this Article I.
"Agreement" means this Natural Gas Facilities Maintenance Agreement, as the same may
from time to time be amended with written consent of Owner and Operator.
"Business Day" means any day except Saturday, Sunday or Federal Reserve Bank
Holidays.
"Commencement Date" shall mean "Nine a.m. Central Clock Time" on April 1, 2025.
"Emergency" means any suspected or actual abnormal condition that has already caused,
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or represents an imminent threat to cause, Facility failure or damage, danger to or loss of
life, pollution, or any hazardous condition.
"Facility" or "Facilities" means the natural gas metering and regulation equipment
belonging to Owner, including all apparatuses, located at the Fairfax Interconnect station
on the Hutchinson Pipeline, the District Regulator Stations serving the Cities of Fairfax
and Gibbon as well as two block valve sites located on the Owner's high-pressure
transmission/distribution line.
"Gas" shall mean natural gas, manufactured, artificial or synthetic gas, or any mixture or
combination thereof.
"Gas Day" shall mean a period beginning and ending at 9:00 a.m., Central Clock Time.
The reference date for any day shall be the date of the beginning of such day.
"Governmental Authority" means (i) the United States of America, (ii) any state, county,
parish, municipality or other governmental subdivision within the United States of
America, and (iii) any court or tribunal or any governmental department, commission,
board, bureau, agency or other instrumentality of the United States of America or of any
state, county, parish, municipality or other governmental subdivision within the United
States of America.
"Law" means any applicable statute, law, ordinance, regulation, rule, ruling, order, decree,
writ, injunction, judgment or other official act of or by any Governmental Authority.
"Maintenance Fee" means the fee for Operator performing Maintenance of the Facilities
and Routine Work.
"Maintenance" means all work or services required to be furnished or performed by
Operator pursuant to this Agreement.
"Operator" means Hutchinson Utilities Commission and its permitted successors and
assigns hereunder.
"Owner" means City of Fairfax and its permitted successors and assigns hereunder.
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"Permits" means all licenses, permits, certificates, orders, approvals and authorizations of
any Governmental Authority necessary for or obtained in connection with operation of the
Facilities or performance of the Operations.
"Person" means any individual, firm, corporation, partnership, joint venture, association,
trust or other entity or organization, including a government or political subdivision or an
agency or instrumentality thereof.
"Routine Worle" includes day-to-day maintenance, testing and repair and more particularly
defined in Exhibit C of this Agreement.
"Non -Routine World" includes work not included in the Routine Work, but shall be
provided on an as -needed basis. Said services and fees are set forth in Exhibit D.
"Year" or "year" means a period of 12 consecutive months commencing with April 1 and
ending on the following March 31.
Section 1.2 References, Gender, Number.
Unless the context requires otherwise, all references in this Agreement to an "Article," "Section"
or "Subsection" shall be to an Article, Section or Subsection of this Agreement, and the words
"this Agreement," "hereof," "hereunder," "herein," "hereby," or words of similar import shall refer
to this Agreement as a whole and not to a particular Article, Section, subsection, clause or other
subdivision hereof. Whenever the context requires, the words used herein shall include the
masculine, feminine and neuter gender, and the singular and the plural.
ARTICLE II: RESPONSIBILITIES OF OPERATOR
Section 2.1 General Responsibilities.
(a) General.
Operator is hereby appointed to perform the Maintenance according to prudent practices
generally followed by the gas pipeline industry under similar circumstances. To the extent
necessary to carry out its duties hereunder, Operator certifies that it is qualified under the
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Operator Qualification Program as required by the federal Department of Transportation
and the Minnesota Office of Pipeline Safety. Operator also certifies that it complies with
the Federal requirements outlined in 49 CFR Parts 40 and 199 pertaining to alcohol and
controlled substance testing. Operator shall provide Owner with the services required for
the testing, maintenance and repair of the Facilities as more fully described below and in
Exhibit C and D. Owner and Operator shall have unrestricted access to the Facilities. It is
expressly understood and agreed that in the performance of its obligations under this
Agreement, Operator is and shall at all times be an independent contractor. Operator, as
an independent contractor, shall be solely responsible for its employees and equipment.
Owner acknowledges that the Maintenance is dependent upon Owner providing Operator
access to the Facilities.
(b) Routine Work.
On and after the Commencement Date, Operator shall perform or cause to be performed
all Routine Work for the Facilities, including but not limited to, repair, improvement,
maintenance, alteration, inspection, testing, protection and other operations and activities
with respect to the Facilities as are reasonably necessary to maintain the Facilities in a
"first-class operating condition" in accordance with the federal safety and maintenance
standards promulgated under 49 CFR Part 192 and the regulations of the Minnesota Office
of Pipeline Safety. The Routine Work is described in greater detail in Exhibit C.
(c) Emergency Work.
Operator will perform all Emergency maintenance and repair of the Facilities consistent
with prudent practices generally followed by the gas pipeline industry under similar
circumstances. Operator will notify Owner of any Emergency condition affecting the
Facilities promptly after Operator learns of such condition and will consult with Owner, as
far as practical, concerning the actions that are necessary. If Owner fails to respond or if
Operator is otherwise unable to consult with Owner, the Operator shall take those actions
that Operator believes are necessary consistent with prudent utility practices and will
contact Owner as soon as possible after the fact.
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Owner will notify Operator after Owner learns of any Emergency condition affecting the
Facilities promptly after Owner learns of such conditions and will consult with Operator,
as far as practical, concerning the actions that are necessary. Operator shall take those
actions that the Operator believes are necessary consistent with prudent utility practices
and will respond promptly to remedy emergency situation.
(d) Scheduling.
To the extent reasonably possible, the performance of repair or maintenance that affects
the operations of the Facilities shall be scheduled to be performed only at times acceptable
to Owner. Except for Emergency or unplanned work, in the event it is necessary to either
interrupt or curtail the gas supply or to otherwise impose abnormal operating conditions on
the Facilities, Owner shall be notified in advance and an agreement must be reached as to
the time scheduled for such work.
(e) Work by Others.
If any part of the Maintenance is dependent upon the quality and completeness of work
performed under another contract unrelated to Operator, Operator shall not be responsible
if the work performed under the other contract is defective or unsuitable and such condition
affects the timing, scheduling or quality of the Operations performed by Operator
hereunder.
Section 2.2 Personnel.
Operator may employ or, contract for, the services of and be responsible for the supervision of
Persons (including consultants and professional, service or other organizations) reasonably
required by Operator to perform the Maintenance in an efficient and prudent manner. The number
of Persons used by Operator in conducting the Maintenance, their hours of work and their
compensation for services performed shall be determined by Operator. All employees and other
personnel provided by Operator pursuant to this Agreement shall be the employees or independent
contractors of Operator and in no event shall such employees or other personnel be deemed
employees or contractors of Owner. On or before the Commencement Date, Operator shall
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designate to Owner in writing a representative who shall be authorized to act on behalf of Operator
as to the Maintenance and with whom Owner may consult at all reasonable times. Operator may
change its representative by written notice to Owner.
Section 2.3 Operator Warranties.
Operator warrants and represents to Owner as follows: Operator shall perform the Maintenance,
and shall require all contractors, subcontractors and materialmen furnishing labor, material or
services for the Maintenance to perform their services and carry out their responsibilities, in a
diligent, safe and efficient manner in accordance with good workmanlike and prudent practices
generally followed by the gas pipeline industry under similar circumstances, but such practices
shall not be less than as may be specifically required by this Agreement. In carrying out such
responsibilities, Operator shall comply, and shall use its reasonable efforts to require all
contractors, subcontractors and materialmen to comply, with all Laws of Governmental
Authorities having jurisdiction. All policies and procedures to be developed by Operator
hereunder shall be available to Owner for its review at Operator's office during normal business
hours.
THESE WARRANTIES ARE EXCLUSIVE AND GIVEN IN LIEU OF ALL OTHER
WARRANTIES WHETHER STATUTORY, EXPRESS, OR IMPLIED (INCLUDING ANY
IMPLIED WARRANTY OF MERCHANTABILITY, FITNESS FOR A PARTICULAR
PURPOSE, NONINFRINGEMENT OF THIRD PARTY INTELLECTUAL PROPERTY
RIGHTS, OR ANY WARRANTY ARISING FROM A COURSE OF DEALING, USAGE, OR
TRADE PRACTICE).
Section 2.4 Owner Warranties.
Owner warrants and represents to Operator that the information it supplies to Operator upon which
the Operations may be based is true and correct to the best of Owner's knowledge.
Section 2.5 Fee for Routine Work.
Fees for Routine work are stated in Exhibit "C".
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Section 2.6 Compensation for Non -Routine Work.
Except for any non -routine expenditure that results from Operator's breach of this Agreement,
negligence, or willful misconduct, Owner shall bear the cost of any direct out-of-pocket
expenditure reasonably incurred by Operator for Non -Routine Work performed in connection with
the Facilities, including labor and materials, plus Operator's overhead as stated in Exhibit "D". .
Any Non -Routine Work that is in excess of $500.00 per event and that is not the result of an
Emergency, will be reviewed and approved by the Owner in advance, subject to Section 2.1(c).
"Non -Routine Work" is defined in more detail in Exhibit D attached hereto.
Section 2.7 Pa n
On or before the fifteenth (15th) day of each calendar month, Operator shall render an
invoice to Owner indicating all fees payable under this Agreement for the preceding
calendar month. Payment is due from Owner on or before the thirty fifth day following
the date the bill is issued by Operator. A late payment charge of one and one-half percent
per month, or the legally authorized maximum interest rate, whichever is lower, shall be
levied on any unpaid balances.
Section 2.8 Owner Duties.
Owner shall fully cooperate with Operator in performing Maintenance. Owner hereby
grants Operator the non-exclusive right to access and use the Facilities, for purposes of and
subject to the terms of this Agreement.
ARTICLE III: TRANSFERS OF RESPONSIBILITIES OF OPERATOR
Section 3.1 Transfer of Responsibilities.
(a) Upon the expiration of this Agreement or the removal of Operator under Section 7.2, the
Operator shall assign, transfer and deliver to the Person selected by Owner to succeed
Operator (or to such other Persons as Owner shall direct) (1) possession and control of the
Facilities and all Operations and (2) to the extent requested by Owner, all contracts,
warranties, operating and maintenance manuals, designs, drawings, operational plans,
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proprietary information and operational rights obtained or entered into by Operator
exclusively with respect to the Facilities or exclusively in connection with the
Maintenance, in each case without giving rise to any penalty, charge, restriction, lien,
security interest, encumbrance, cancellation, termination, acceleration or change in terms
not previously approved by Owner. Operator shall fully cooperate with Owner in transfer
of Maintenance hereunder to Owner or a successor operator designated by Owner. Upon
termination, Operator shall return to Owner all original records and any materials
purchased by Operator and paid for by Owner, such as pretested pipe, valves and other
miscellaneous materials and supplies.
(b) As soon as practicable after the date on which the Operator is required to transfer its
responsibilities as provided in Article III (a), Owner may conduct an audit and inventory
of the Facilities and all of Owner's assets and properties operated, managed or controlled
by Operator. Such audits and inventory shall be used in the return of and the accounting
for the Facilities and Owner's properties and assets by Operator for the purposes of the
transfer of responsibilities under Article III. All costs and expenses incurred in connection
with such audits and inventory shall be borne by Owner.
ARTICLE IV: INSURANCE
Section 4.1 Owner's Insurance.
Owner shall procure and maintain in full force and effect, at the Owner's cost, all risk property
insurance in an amount equal to the full insurable value of the Facilities.
Section 4.2 Operator's Insurance.
Operator shall procure and maintain in full force and effect at the Operator's cost, the following
insurance coverage:
(a) Worker's Compensation and Employer's Liability insurance in accordance with the laws
of Minnesota with limits for Employer's Liability of $1,500,000 per accident or disease,
aggregate as disease.
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(b) Business automobile liability insurance covering owned, non -owned and hired vehicles
with minimum combined single limits for bodily injury and property damage for any single
loss of $2,000,000.
(c) Commercial general liability insurance with completed operations coverage for claims
alleging bodily injury including death and damage to property of others, with a combined
single limit of $2,000,000 for bodily injury and property damage per occurrence and
$3,000,000 in the aggregate.
(d) Excess liability insurance for claims alleging bodily injury including death and damage to
property with a combined single limit of $5,000,000 for bodily injury and property damage
per occurrence and in the aggregate.
Section 4.3 Other Insurance Requirements.
Each Party shall be listed as an additional insured with respect to the insurance coverage required
under this Article IV. All insurance policies shall be endorsed to provide that all insureds and
additional insureds hereunder be given thirty (30) days' advance notice of cancellation or material
change. Within thirty (30) days of the date of this Agreement, each Party shall furnish to the other
Party certificates as evidence showing that the insurance policies to be carried in accordance with
this provision have been obtained.
Section 4.4 Maximum Liability.
Operator's maximum liability is limited to a combined single limit of $1,500,000 by Minnesota
Statute.
ARTICLE V: FORCE MAJEURE
Section 5.1 Performance Excused.
If any Party is rendered unable, wholly or in part, by force majeure to carry out its obligations
under this Agreement, other than the obligation to make money payments or to furnish security,
that party shall give to all other parties prompt written notice of the force majeure with reasonably
full particulars concerning it; and thereupon, the obligations of the party giving notice, so far as
they are affected by the force majeure, shall be suspended during, but no longer than, the
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continuance of the force majeure. The party claiming force majeure shall notify the other parties
of the force majeure situation within a reasonable time after the occurrence of the facts relied on
and shall keep all parties informed of all significant developments. Such notice shall give
reasonably full particulars of said force majeure, and also estimate the period of time, which said
party will probably require to remedy the force majeure. Force Majeure does not relieve the
operator of the contractual responsibilities to operate the Facilities; provided that, the Facilities
can be operated utilizing reasonable and safe methods. The affected party shall use all reasonable
diligence to remove the force majeure situation as quickly as practicable in an economic manner.
The requirement that any force majeure shall be remedied with all reasonable dispatch, shall not
require the settlement of strikes, lockouts or other labor difficulty by the party involved, contrary
to its wishes; how all such difficulties shall be handled shall be entirely within the discretion of
the party concerned.
Section 5.2 Force Majeure Defined.
The term "force majeure", as here employed, shall mean an act of God, strike, lockout or other
industrial disturbance, act of the public enemy, war, blockade, public riot, lightning, fire, storm,
flood, earthquake, explosion, pandemic, governmental action, governmental delay, restraint or
inaction, unavailability of equipment/supply chain issues and any other cause, whether of the kind
specifically enumerated above or otherwise, which is not reasonably within the control of the party
claiming suspension.
ARTICLE VI: ASSIGNMENT
Section 6.1 Assignment by Owner.
Owner may not assign all or any part of its rights or obligations under this Agreement without
prior written consent of Operator.
Section 6.2 Assignment by Operator.
Operator may not assign all or any part of its rights or obligations under this Agreement without
the prior written consent of Owner. Such approvals shall not be unreasonably delayed, withheld
or conditioned.
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ARTICLE VII: TERM
Section 7.1 Term.
This Agreement shall become effective on the Commencement Date and shall continue in force
and effect until "Nine a.m. Central Clock Time" on April 1, 2026, and year-to-year thereafter,
subject to termination.
(a) Owner shall notify Operator in writing ninety (90) days prior to the expiration date of this
Agreement as to Owner's desire for Operator to continue maintenance of the Facility.
Operator shall respond in writing to Owner within thirty (30) days of receipt of Owner's
notice and on or before sixty (60) days prior to the expiration of this Agreement regarding
the Operator's desire to continue as Operator.
Section 7.2 Default and Termination.
Upon failure by either Party in the performance of any provision, condition or requirement herein,
the other Party may give notice in writing to the defaulting party specifying the default. Unless
such default is cured within thirty (30) days following receipt of such notice to the defaulting Party,
or if such default is susceptible of being cured and such cure cannot be completed with such thirty
(30) days period, then if the cure thereof is not undertaken promptly upon receipt of such notice
and diligently prosecuted thereafter, this Agreement may be terminated within sixty (60) days of
the date of the notice claiming default was written at the option of the Party serving such notice of
default.
Section 7.3 Effect of Termination.
Termination of this Agreement shall not relieve either Party from any obligation including
payments due for Operations as provided in this Agreement, accruing to the date of such
termination or relieve any Party of any liability for its breach of this Agreement. Article III shall
survive any termination of this Agreement.
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ARTICLE VIII: MISCELLANEOUS
Section 8.1 Governing Law.
This Agreement shall be governed by and construed in accordance with the laws of the State of
Minnesota without reference to the choice or conflict of law, rules or principals thereof which
would refer the matter to the laws of another jurisdiction.
Each Party shall abide by the Laws of any Governmental Authorities with jurisdiction over the
matters of this Agreement, as may be amended from time to time.
Section 8.2 Entire Agreement.
This Agreement and the Schedules and Exhibits hereto contain the entire agreement between the
Parties with respect to the subject matter hereof and there are no agreements, understanding,
representations or warranties between the parties other than those set forth or referred to herein.
Section 8.3 Notices.
Except as otherwise specifically provided, all notices authorized or required between the Parties
by any of the provisions of this Agreement, shall be in writing, in English and delivered in person
or by registered mail or by courier service or by any electronic means of transmitting written
communications that provides confirmation of complete transmission, and addressed to such
Parties as designated below. The originating notice given under any provision of this Agreement
shall be deemed delivered only when received by the Party to whom such notice is directed, and
the time for such Party to deliver any notice in response to such originating notice shall run from
the date the originating notice is received. The second or any response notice shall be deemed
delivered when received. "Received", for purposes of this Section with respect to written notice
delivered pursuant to this Agreement, shall be actual delivery of the notice to the address of the
Party to be notified, specified in accordance with this Section. Each Party shall have the right to
change its address at any time and/or designate that copies of all such notices be directed to another
Person at another address, by giving written notice thereof to all other Parties.
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City of Fairfax
18 18t St. SE
Fairfax, MN 5539655332
Attention: Andrea Merkel
City Administrator
E-Mail: Admin@fairfax-mn.gov
Telephone No.: 507-426-7255
Hutchinson Utilities Commission
225 Michigan St. SE
Hutchinson, Minnesota 55350
Attention: Jeremy Carter
E-Mail: jcarter@hutchinsommn.gov
Telephone No.: 320-234-0505
Fax No.: 320-587-4721
Section 8.4 Successors and Assigns.
Subject to the restrictions and requirements on assignment and transfer contained in this
Agreement, this Agreement shall be binding upon and inure to the benefit of the Parties hereto and
their respective successors and assigns.
Section 8.5 Headings.
The headings to Articles, Sections and other subdivision of this Agreement are inserted for
convenience of reference only and will not affect the meaning or interpretation of this Agreement.
Section 8.6 Amendments and Waivers.
This Agreement may not be modified or amended except by an instrument or instruments in
writing, signed by all Parties. Any Party may, only by an instrument in writing, waive compliance
by another Party hereto with any term or provision of this Agreement on the part of such other
Party hereto to be performed or complied with. The waiver by any Party of a breach of any term
or provision of this Agreement shall not be construed as a waiver of any subsequent breach.
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Section 8.7 Schedules and Exhibit.
All Schedules and Exhibits to this Agreement are hereby incorporated by reference.
Section 8.8 Agreement for the Parties' Benefit Only.
This Agreement is not intended to confer upon any Person not a party hereto or a permitted
successor or assign of a Party any rights or remedies hereunder, and no Person, other than the
Parties or a permitted successor or assign thereof, is entitled to rely on any covenant or agreement
contained herein.
Section 8.9 Severability.
If any term or other provision of this Agreement is invalid, illegal or incapable of being enforced
by any rule of law or public policy, all other conditions and provisions of this Agreement shall
nevertheless remain in full force and effect so long as the economic or legal substance of the
transactions contemplated hereby is not affected in any adverse manner to any party. Upon such
determination that any term or other provision is invalid, illegal or incapable of being enforced,
the parties hereto shall negotiate in good faith to modify this Agreement so as to effect the original
intent of the parties as closely as possible in an acceptable manner to the end that the transactions
contemplated hereby are fulfilled to the extent possible.
Section 8.10 Independent Contractor; No Partnership.
Operator shall perform its duties and obligations hereunder as an independent contractor, and
nothing contained herein shall be deemed to create a relationship of employer/employee,
master/servant, agency, partnership or joint venture. This Agreement is not intended to create, and
shall not be construed to create, a relationship of partnership or an association for profit between
Operator and Owner.
Section 8.11 Data Practices Act.
The Parties acknowledge that Operator is subject to Minnesota Government Data Practices Act,
Minnesota Statutes, Chapter 13 (the "Act"), including limiting public access to trade secret and
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other protected data. Each Party agrees to defend, indemnify, and hold harmless the other Party,
its officials, officers, agents, employees, contractors, and subcontractors from any claims resulting
from unlawful disclosure and/or use of such protected data. Owner agrees to promptly notify
Operator if Owner receives a request to access the terms of this Agreement, and to cooperate with
Operator if Operator seeks a protective order, at Operator's expense. Owner agrees to promptly
notify Operator if Owner becomes aware of any potential claim, or facts giving rise to potential
claims, under the Act. The terms of this section shall survive the termination of this Agreement.
Section 8.12 News Releases.
News releases concerning the Maintenance or the Facilities shall only be made in accordance with
the following guidelines, subject to the requirements of applicable laws and governmental rules
and regulations:
No public announcement or statement shall be issued by Operator unless prior to its release Owner
has been furnished with a copy of such statement or announcement and the reasonable approval of
the Owner has been obtained. Where a public announcement or statement becomes necessary or
desirable because of an Emergency as a result of activities arising under this Agreement, Operator
is authorized to issue and make such announcements or statements without prior reasonable
approval of the Owner, but shall promptly furnish Owner with a copy of the announcement or
statement.
Section 8.13 Authority to Enter Agreement.
Each party to this Agreement represents and warrants that it has full and complete authority to
enter into and perform this Agreement. Each person who executes this Agreement on behalf of
either party represents and warrants that it has full and complete authority to do so and that such
party will be bound thereby.
Section 8.14 Alternative Dispute Resolution.
Whenever the Parties disagree on the interpretation or enforcement of this Agreement, or upon
calculations or payments, then upon written request of either Party, representatives with settlement
authority for each Party shall meet in person and confer in good faith to resolve the dispute. If the
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Parties are unable to resolve the dispute, they shall submit their dispute to mediation pursuant to
the Minnesota Civil Mediation Act. If the dispute is not resolved by mediation, the Parties may
invoke their legal remedies available at law.
Section 8.15 Counterparts.
This Agreement may be executed in counterparts, and each executed counterpart shall have the
same force and effect as an original instrument.
ARTICLE IX: LIABILITY; INDEMNITY
Section 9.1 Indemnification by Owner.
Owner shall defend, protect, indemnify, and hold harmless Operator, and its members, directors,
officers, employees and agents from and against all liability, claims, liens, costs, expenses,
demands, fines or other actions imposed by any Governmental Agency with jurisdiction, suits and
causes of action of every kind and character arising in favor of any third party on account of
personal injuries or death, or damages to property (including without limitation claims for
pollution and environmental damage) in any way directly resulting from the negligent acts or
omissions of the Owner, its agents, employees, representatives, or contractors, or from the failure
of Owner, its agents, employees, representatives, or contractors to perform its obligations under
this Agreement and in compliance with all applicable Laws. This indemnity includes Owner's
agreement to pay all costs of defense, including without limitation attorneys' fees, incurred by any
person or party indemnified herein.
Owner acknowledges that utility equipment malfunction or failure may occur notwithstanding the
inspection, maintenance, and repair work performed hereunder, and hereby indemnifies, releases,
and holds Operator harmless from any claim or liability, and any direct or indirect damages
claimed or actually suffered (including, without limitation, consequential damages and loss of
profits), resulting from any utility equipment malfunction or failure occurring during the term of
this Agreement, except such claims or liability directly resulting from the negligent acts or
omissions of Operator.
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Section 9.2 Indemnification by Operator,
Subject to Section 2.1 (c), Operator shall defend, protect, indemnify, and hold harmless Owner,
and its members, directors, officers, employees and agents from and against all liability, claims,
liens, costs, expenses, demands, fines or other actions imposed by any Governmental Agency with
jurisdiction, suits and causes of action of every kind and character arising in favor of any third
party on account of personal injuries or death, or damages to property (including without limitation
claims for pollution and environmental damage) in any way directly resulting from the negligent
acts or omissions of Operator, its agents, employees, representatives, or contractors, or from the
failure of Operator, its agents, employees, representatives, or contractors to perform its obligations
under this Agreement and in compliance with all applicable Laws. This indemnity includes
Operator's agreement to pay all costs of defense, including without limitation attorneys' fees,
incurred by any person or party indemnified herein.
Operator agrees that the obligations of indemnification herein include, but are not limited to, liens
by third parties against Owner and its property because of labor, services, materials, or any other
subject of lien, furnished to Operator or its assignees or subcontractors, in connection with any
work performed by Operator hereunder.
Section 9.3 No Consequential Damages
Under no circumstances shall either Party hereto be liable to the other hereunder for indirect,
special, consequential or similar damages, or for loss of profits.
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John Webster
WHEREFORE, the Parties have executed this Agreement in two (2) duplicate originals
by their duly authorized, respective officers, effective as of the date specified above.
HUTCHINSON UTILITIES
COMMISSION
in
Name:
Title: Commission President
Date:
Witness:
Date:
Witness:
Date:
Dp—von, and Miunt.,— Agree n-1
Nm—1 GH, Facilities
City oi F-Cm
Jo1111 WLbslT
18
By: —
Name:
Title:
Date:
Witness:
Date:
Witness:
Date:
CITY OF FAIRFAX
EXHIBIT "A"
This Exhibit "A" is attached to and made part of that certain Maintenance Agreement — Natural
Gas Facilities (the "Agreement") by and between City of Fairfax ("Owner") and Hutchinson
Utilities Commission ("Operator").
OPERATOR'S PAYMENT INSTRUCTIONS:
For the purpose of this Agreement, Owner shall make all payments provided in the Agreement to
Operator via Check to the following:
Hutchinson Utilities Commission
225 Michigan St SE
Hutchinson, Minnesota 55350
EXHIBIT "B"
This Exhibit `B" is attached to and made part of that certain Maintenance Agreement — Natural
Gas Facilities (the "Agreement") by and between City of Fairfax ("Owner") and Hutchinson
Utilities Commission ("Operator").
Owner has constructed (or will construct) and own the natural gas facilities, including all
apparatuses, located at the Fairfax Interconnect station on the Hutchinson Pipeline, the District
Regulator Stations serving the Cities of Fairfax and Gibbon as well as the two Block Valve Sites
located on the Owner's high-pressure transmission/distribution line, appurtenances thereto,
("Facility" or "Facilities") serving City of Fairfax, Fairfax, Minnesota.
Each interconnected third party natural gas operator shall operate their respective pipeline facilities
connected to the Facilities.
EXHIBIT "C"
This Exhibit "C" is attached to and made part of that certain Maintenance Agreement — Natural
Gas Facilities (the "Agreement") by and between City of Fairfax ("Owner") and Hutchinson
Utilities Commission ("Operator").
ROUTINE WORK
All labor shall be charged at a cost plus 50% of the Operator hourly rate in affect at the time of
the work being performed multiplied by the number of hours required by the employee(s) to
complete Maintenance work for Owner.
Hours required to complete Maintenance includes travel time from Operators' work center to job
site including return trip to Operator's work center.
Operator non -overtime rate - $63/hour
Operator vehicle hourly rate - $47/hour
All materials shall be charged at a cost plus 15% to cover all inventory and purchasing fees.
COMPLETE LIST OF ROUTINE ITEMS:
A. Maintenance, Repair and Security
1. Perform routine station meter testing and calibration
2. Maintain, test and repair all station and high-pressure block valves
3. Maintain, test and repair regulators
4. Maintain and repair station line heater
5. Maintain and repair station odorizer
6. Maintain the cleanliness and environmental soundness of the Facilities
7. Make mechanical repair
8. Perform preventative maintenance
9. Respond to emergency calls during HUC standard work hours (6:30 AM to 5:00 PM,
Monday through Friday), except to the extent response to an emergency requires
additional personnel that are not on duty during said emergency and/or additional
outside contractors
B. Legal and Regulatory Compliance
1. Maintain DOT System records
2. Maintain Training & DOT Operator Qualification Program and records
EXHIBIT "C", continued
3. Maintain Anti -Drug and Alcohol compliance programs
4. Maintain operating procedures, maintenance procedures, and training plans and
procedures to be followed for Maintenance, and ensure procedures and plans are
available for review by Owner in Operator's office during normal business hours
5. Maintain Emergency Response Plan, Operation & Maintenance Manual, and Operator
Qualification Plan, including annual updates
6. Reporting to Owner any notices of violations of any Laws or Permit provisions
7. Otherwise maintain the Facilities' and Operations' ongoing compliance with all Laws
and Permits
C. Monitoring and Testing
1. Witness third party meter calibrations at the request of Owner.
2. Perform monthly odorization monitoring
3. Maintain proper documentation on all inspections, tests and calibrations
D. Other
1. Maintain in force and effect, and require all contractors (and their subcontractors)
performing services for the benefit of Owner to maintain in force and effect, insurance
of the types and in the amounts specified by Owner.
2. Undertake all reasonable efforts to keep the Facilities, all contracts relating to the
Maintenance, and all property and rights of Owner free and clear of any and all liens,
encumbrances, security interests, charges, claims and restrictions arising out of or on
account of the Operations
3. Maintain 24-hour emergency telephone number
4. Procure and furnish all equipment, services, supplies, labor and supervision necessary
to carry out Operator's responsibilities under this Agreement.
EXHIBIT "D"
This Exhibit "D" is attached to and made part of that certain Maintenance Agreement — Natural
Gas Facilities (the "Agreement") by and between City of Fairfax ("Owner") and Hutchinson
Utilities Commission ("Operator").
NON -ROUTINE WORK
EXAMPLE OF NON -ROUTINE ITEMS: Expense **
1. After -hours, holidays, weekends emergency response Cost + 80%
2. Additional personnel as my be required
during emergencies
Cost + 80%
3. Additional contractors as may be required
during emergencies Cost + 50%
4. Any and all other items relevant to the
metering and regulation facility operation and
maintenance that are neither listed above
nor included in the attached Exhibit C. Cost + 50%
** "Expense", as referenced above, shall be the cost of materials, equipment and third -
party labor to complete the applicable work or project. Operator shall invoice such cost plus
listed overhead. In addition, thereto, Operator shall charge $63.00 per man-hour for non -
overtime work. All vehicles and equipment shall be charged by the amount reflected in the
following table. All labor shall be billed at the appropriate hourly rate; straight time, time and
one-half or double time dependent on time of day and day of week work was required.
EXHIBIT "D", continued
Labor and Equipment Rates (per Hour)
AIR COMPRESSOR $42.00
WELDER $52.00
BACKHOE $80.00
VEHICLE $47.00
OPERATOR $63.00
HUTCHINSON UTILITIES COMMISSION �CHINS�
Board Action Form
�XPAIXZ''
Approval of Highland Park Industrial, LLC Natural Gas Transportation and Commodity
Agenda Item: Agreement
Presenter: GM Jeremy Carter
Agenda Item Type:
Time Requested (Minutes):
New Business
Attachments: Yes
BACKGROUND/EXPLANATION OFAGENDA ITEM:
Highland Park Industrial, LLC currently transports base load and daily swing supplies of
natural gas on Hutchinson Utilities' transmission and distribution systems. Highland
Park Industrial LLC's current agreement expires on May 1, 2025 at 9 A.M.. This
agreement provides transportation rights to Highland Park Industrial, LLC on
Hutchinson's facilities from May 1, 2025 at 9.00 A.M., through May 1, 2026 at 9.00 A.M..
All fees are in alignment with the rate realignment structure adopted by the Commission
for this customer.
BOARD ACTION REQUESTED:
Approval of the Highland Park Industrial, LLC Natural Gas Transportation and
Commodity Agreement
Fiscal Impact: Approx. $65,000 per year
Included in current budget: Yes Budget Change: No
PROJECT SECTION:
Total Project Cost: Remaining Cost:
ImMulm
LF01 On. 161,i
THIS • *MADE AND
ENTERED INTO THIS 30TH DAY OF APRIL, 2025, TO BE
EFFECTIVE AS OF THE 1 ST ■ a ` OF MAY,AND
i, s r w
HUTCHINSON UTILITIES • i
MINNESOTA MUNICIPAL LOCATED
D AT
MICHIGy *,,.
HIGHLAND PARK INDUSTRIAL, AND r
;;AALL HEREINAFTER SOMETIMES BE REFERRED TO
SEPARATELY
L ►A L "PARTY" OR JOINTLY AS "PARTIES."
HIGHLAND PARK
y ► INDUSTRIAL,
} DESIRES
} � a �1 "' i ►. � ► v J� 9
WHEREAS, HIGHLAND PARK INDUSTRIAL, LLC DESIRES
TO PURCHASE. y,.. HUC SHALL PROVIDE,
NATURAL Ia. TRANSPORTATION
r O r y i` � ► USE AT HIGHLAND
PARK ., .. } PLANT;
1 L
WHEREAS, HIGHLAND PARK
y ► INDUSTRIAL. 1E
ACKNOWLEDGE L RELIANCE
T HUC WILL, IN
THIS AGREEMENT, ENTER INTO AN AGREEMENT Tij
PROVIDE FIRM GAS AND TRANSPORTATION.
�c
THEREFORE,IN CONSIDERATION
OTHER GOOD AND VALUABLE CONSIDERATION, RECEIPT
HEREBY ACKNOWLEDGED, THE PARTIES MAKE THE FOLLOWING AGREEMENT:
T41 LLC SHALL ACCEPT,
FIRM GAS AND TRANSPORTATION, COMMENCING MAY 1, 2025, AT 9:00 A.M.
I. Av-&LABILnY
FIRM TRANSPORTATION
SERVICE
SHALL BE AVAILABLE TO ' ii -+- INDUSTRIAL,
UNDER THE TERMS AND CONDITIONS OF THIS AGREEMENT.
INTERRUPTEDSERVICE MAY NOT BE CURTAIL-ED OR EXCEPT
PURSUANT TO THE TERMS OF THIS AGREEMENT.
SERVICEB. THE COST FOR ADDITIONAL CAPACITY OR NEW INSTALLATIONS
UTILIZING THIS SHALLBE BILLED .. HIGHLAND PARK
INDUSTRIAL,-+r INDUSTRIAL,
SUBMIT A WRITTEN REQUEST li ' ADDITIONAL
CAPACITY/NEW INSTALLATIONS. ALL ADDITIONAL COSTS MUST
BE PRE -APPROVED, -ITING, BY HIGHLAND -A- INDUSTRIAL,
SERVICEi AGREEMENT
UNTIL BOTH PARTIES HAVE FULLY EXeCL)TFn
- ♦, AEV-1TRE-RiErITS CONTAINED
0 a r i
HUC +S THE RIGHT MODIFYAGREEMENT
i DUE O
CHANGES IMPOSED
#is BY
L GAS
TRANSMISSIONPROVIDERS ANi' FEDERAL, STATEAND LOCAL
-
REGULATORS/AUTHORITIES.
2 M-
THE TERM FOR SERVICE UNDER THIS i
HIGHLANDHIGHLAND PARK INDUSTRIAL, LLC MUST NOTIFY HUC IN WRITIN
THREE (3) MONTHS -
E EXPIRATION OF,THE TERM I
PARK INDUSTRIAL,
DESIRES
AGREEMENT.
COMPLIED WITH ALL TERMS OF THIS AGREEMENT, AND HAS 14,144
lt! ♦ ! 1 ► ► i ► ♦ h n Y n I� 4i ♦ a
n ► fl F � � :' a it . , r �, - li i
THE FOLLOWING CHARGES a APPLY f
�I Ali ♦ � r � .� n ♦ � a � a fr u` ►'�� �I �;
�� a � tea► � ► a
� ! i
� a r a ♦ ► a a n .n � a •�
MONTHLY INDEX AS PUBLISHED PFERC LATTS a
VENTURA,MARKET REPORT FOR NORTHERN NATURAL GAS CO. AT
IOWA PLUS OR MINUS ANY PREMIUM
r OR
DISCOUNT BASED ON ♦ Al -
THE
GAS D
IN THE EVENT THAT r MF INTO A
SHALL"COMMODITY PRE -PAY PURCHASE PROGRAM" (CPPP),
HUC OnDINaTE WITH HIGHLAND rair H
INDUSTRIAL, PLACEnn
PURCHASED FOR HIGHLAND PARK INDUSTRIALwh&9mwffi=V,
THE HLIC CPPP. HIGHLAND PARK INDUSTRIAL, LLC MAY
PLACE a a* PRE -PURCHASED
MONTHLYDAILY VOLUMES INTO THE CPPP. HUC SHALL MANAGE
THE PLACED
a A►
i FF � ON
BEHALFHIGHLAND PARK INDUSTRIAL,
n; a
HLIC IS CURRENTLY PROVIDING a CPPP DISCOUNT TO
INDEX OF $0.04 PER DTHI. THIS DISCOUNT IS IN EFFECT
r THROUGH O
HIGHLANDHILIC SHALL PURCHASE PARFIRM K INDUSTRIAL'S, a LOAD NAT a IF r •►
DEMAND2, MONTHLY CHARGE
DEMANDMONTHLY ... n
$10.33
MCF OF BILLING DEMAND
3. TRANSPORTATION
(TRANSMISSION - .0 DT
(DISTRIBUTION: 0rR
4. MONTHLY METER CHARGE
METER FEE - $429/METER
5. TAXES
TH E ABOVE CHARGES DO NOT INCLUDE .
HIGHLAND PARK INDUSTRIAL, COSTS
ASSOCIATED WITH THE INSTALLATION OF METERS AND ANY
OTHER EQUIPMENT NECESSARY FOR HIGHLAND PARK
INDUSTRIA
- -
�E _N TO SUPPLYS SYSTEM
ALL OR ANY PORTION OF THE TRANSPORTATION CUSTOMER'S DAILY
REQUIREMENTS.
THE RECONNECTION CHACALCULATED ON A MONTHLY
BASIS AND SHALL CONSIST
APPLIES - ■ BY HIGHLAND PARK
INDUSTRIAL'S INDUSTRIAL
A. TERM
IX MONTHS - COMMENCING IT FIRST
FOLLOWING I ION OF THIS AGREEMENT
B. REALIGNMENT SURCHARGE
THE REALIGNMENT SURCHARGE BE ADDITION TO THE
INDUSTRIALRATE AS PUBLISHEDs
MONTHLY■
By .. . D,
ILY", PLUS/MINUS THE NNI
TENTURA To NBPL VENTURA MONTHLY PREMIUM MINUS
HOWEVER, THAT SUCH SURCHARGE SHALL NEVER BE
LESS THAN •f
-. ■ . . -
HIGHLANDMIS
ANYTIME WITHOUT PENALTY.
IN THE EVENTTHAT PARKIN
■ .
■ -•-
+■ . ■ M ■� - - .��
■ -■
SECTIONCOMPLY WITH RECONNECTION
ABOVE.
MEMEARRM
INVOICE WILL BE RENDERED TO HIGHLAND PARK INDUSTRIAL,
LLC, OR ITS AGENT, BY THE FIFTEENTH DOF •
FOLLOWINGwNTH IN WHICH SERVICE IS RENDERED
BEFOREDAY FOLLOWINGDATE THE BILL IS
ISSUED By HUC. A LATE PAYMENT CHARGEAND
PER MONTH, THE LEGALLY AUTHORIZED
INTERESTMAXIMUM RATE, - IS LOWER,
x ON ANY UNPAID BALANCE.
A HUC HEREBY CERTIFIES HAS SUFFICIENT FIRM
TRANSPORTATION SERVICE TO HIGHLAND PARK INDUSTRIAL, LLC
PURSUANT TO THE TERMS OF THIS AGREEMENT FOR THE TERM
TRANSPORTATION CAPACITY TO PROVIDE THE AMOUNT OF FIRM
_,ITNLESS OTHERWISE - D BETWEEN HIGHLAND PARYI
INDUSTRIAL, LLC AND HUC, HIGHLAND PARK INDUSTRIAL, LLC
. .' ".N w,- I WOMENBOXimirl rem.211013m
SHALLHUC ► a WRITTEN ESTIMATEi PA
INDUSTRIAL,ALL ASSOCIATED
INSTALLATION OF REQUIRED METERING AND
OTHER EQUIPME
NECESSARY FOR HIGHLAND PARK INDUSTRIAL, LLC TO RECEIJm
SERVICE UNDER THIS AGREEMENT. HIGHLAND ► a
INDUSTRIAL, LLC MUST PROVIDE WRITTEN APPROVAL To HU
AUTHORIZING PURCHASE OF SAID EQUIPMENT. 31
C. UNLESS OTHERWISE AGREED TO IN WRITING BY HUC AND
HIGHLAND PARK INDUSTRIAL, AUTOMATIC ..
EQUIPMENT REQUIRED. HIGHLAND PARK INDUSTRIAL,
SHALL .. TELEPHONE,. R AND OTHER
INTERFACES, AS WELL AS i •
METER(S), AS ► i TO BY HIGHLAND PARK INDUSTRIAL,
AND HUC. ALL MONTHLY UTILITY FEES (TELEPHONE,
ELECTRICITY, ETC.) SHALL BE BORNE r
INDUSTRIAL, a i PARK INDUSTRIAL,SHALL
PROVIDE
..iHUC WITH ACCESS SO THUCHATMAY P . 4 AND
MAINTAIN SAID EQUIPMENT.
D. MUC SHALL PROVIDE HIGHLAND PARK INDUSTRIAL, LLC (OR
AGENT) a DAILY aGE REPORT a. EMAIL FOR
NOMINATION PURPOSES.
,:
FIRSTA. MONTHr '. a f
By /' A.M.a
DAY OF THE MONTH PRIOR TO GAS FLOW, HIGHLAND PARK
INDUSTRIAL, OR ITS DESIGNATED AGENT, SHALL
HUC A
WRITTEN ESTIMATEa i PARK INDUSTRIAL'S
DAILY .., BASE
a NATURAL a REQUIRED
'Qri FOR
FOLLOWINGTHE OHAS i
RECEIVED THE BASE LOAD NOMINATION. HIGHLAND PARK
INDUSTRIAL, LLC BY THE ABOVE DESIGNATED TIME, HUC SHALL
NOMINATE BASE LOAD t THE
FOLLOWINGit
�o rm LVA 1164 no#
■a .r' *. aa a mKol.IM-MMI
i
THE GAS DAY SHALL RUN FROM 9:00 A.M. TO 9:00 A.
CENTRAL STANDARD TIME. I
TFAEREAS,HIGHLAND PARK INDUSTRIAL, SHALL
OF PRICING L ! fAMONTHLY
DAILY AND PURCHASESi
L k i i L iy; y Ili Y Y ■I"
i �. ♦ � i L M .. L i. � ; . a �
C. ALL I i Y PURCHASED HIGHLAND Lii
INDUSTRIAL,y BE ■ 1f ON THE NORTHERN
BORDER PIPELINE
i ... i rrIMONT DELIVERY
POINT.
V. a a i ALL ♦ PARK y
L, LLC
QUANTITIES FROM THEHUCPIPELINE
RECEIPT TO THE HIGHLANDPARK INDUSTRIAL,
LLC/HUTCHINSON PLANT AS s AND
TRANSPORTATIONAGREEMENT" CURRPLACE,
RENEWED ANNUALLY, BETWEEN HUC AND HIGHLAND PARK
Yi,
INDUSTRIAL,
E. HUC SHALL PROVIDE TO HIGHLAND PARK INDUSTRIAL, LLC, FOR
EACH NATURAL y PURCHASE,
!. y "TRANSACTION
i Y
COMPLETED.
CONFIRMATION"
y 1 O �� L PROOF
i l� O THAT THE PURCHASE
L WAS
fl, i ', "TRANSACTION CONFIRMATION"
Y SHALL
PROVIDE DETAILS OF NATURAL
L . PURCHASE Y
DELIVERY PERIOD
i ♦ r. DELIVERY PERIOD
Y!. ! DATE,
TOTAL QUANTITY By DELIVERY Irt POINT
i` ♦ D
CONTRACT PRICE.
F. llI AND HIGHLAND PARK
y i INDUSTRIAL,
L AGREE ♦ ALL
NATURAL L PURCHASED HIGHLAND PARK INDUSTRIAL,
SHALLLLC REMAIN
. PROPERTY
r.i i OF HUC UNTIL SOLD TO
HIGHLAND PARK INDUSTRIAL, LLC ON A DAILY BASIS. ONCE THE
NATURAL GAS VOLUMES HAVE i 'r METERED, BY i
METERING FACILITIES, THEY BECOME THE PROPERTY
HIGHLAND PARK INDUSTRIAL, LLC. ALL DAILY VOLUMES F
EACH i1M f TO HIGHLAND ►, I"
DUST+;+ OR�ITS AGENT, BY DAY OF T
MONTH• MMONTH
RENDERED
G. ALL VOLUMES PLACED INTO THE CPPP BY HIGHLAND PARK
INDUSTRIAL,BE i BY HIGHLAND ►+;.
INDUSTRIAL, *I + DAILY BASIS. DAILY
+ IMBALANCES
'+y
i P P VOLUMES ARE NOT PERMITTED.
H. HIGHLAND PARK INDUSTRIAL, + HAVE ABILITY
CEASE PARTICIPATION IN THE
.+Ii4 ifs UPON +CH RENEWAL
THIS AGREEMENT. IN THE EVENT + ■ PARK INDUSTRIAL,
LLC CHOOSES NOT TO PARTICIPATE IN THE CPPP, FUTURE
PARTICIPATION PERMITTED.
HIGHLAND1. IN THE EVENT THAT PARKINDUSTRIAL,,
LONGER HAS THE ABILITY• CONSUME
OF NATURAL GAS PLACED INTO THE CPPP, HIGHLAND PARK
INDUSTRIAL,SHALL
HIGHLAND PARK INDUSTRIAL, LLC CHOOSES TO CEASE
PARTICIPATION wi E iri HUC SHALL WORK WITH THE
PE PROVIDER TO REMODESIGNATED HIGHLAND PARK
INDUSTRIAL, LLC VOLUMES.M THE r r r. ONCE HIGHLAND
PARK +S CEASED PARTICIPATION
SHALL
K. IN THE EVENT THAT HIGHLAND PARK INDUSTRIAL,
LONGER HAS THE ABILITY TAKE THE CONTRACTED NATURAL
AMOUNTGAS COMMODITY PURCHASED UNDER THIS AGREEMENT, DUE TO
PLANT TEMPORARY SHUTDOWN, PERMANENT CLOSURE, ETC.,
HIGHLAND PARK INDUSTRIAL, LLC SHALLTURN BACK TO HUC AN
EQUAL REMAINING CONTRACTED QUANTITY,
FOR + FINANCIAL ADJUSTMENT BE MADEBASED ON a.
HIGHLANDFORMULA EQUAL TO THE QUANTITY OF GAS TO BE TURNED BACK
BY PARK INDUSTRIAL, MULTIPLIED BY THE
DIFFERENCE APPLICABLE CONTRACT PRICE AND
THE GDD PRICE FOR
. ,, DAILY ► . �� ► .
iu �. E � MEANS
THE GAS DAILY NNG VENTURA INDEX FOR THE DAY OF DELIVERY
"` THE DELIVERIES TO VENTURA.
L. IN THE EVENT MONTHLY QUANTITIES ARE TO BE TURNED BACK
o HILIC, THE SETTLEMENT FORMULA SHALL BE EQUAL TO THE
QUANTITY OF GAS TO BE TURNED BACK MULTIPLIED
DIFFERENCE BETWEENAPPLICABLE CONTRACT
INSIDETHE i OF MONTH:
VENTURAPLUS/MINUS THE NNG To NBPLVENTURA MONTHLY
CONSIDERATION.PREMIUM FOR THE MONTH IN
HUC AGREES TO PROVIDE DAILY SWING SUPPLY r
INDUSTRIAL, LLC AT THE APPLICABLE PRICE, PUBLISHED FOR THE
DAY BY s aTT'S "GAS DAILY". PRICESURVEY M
OR VENTURA" "MIDPOINT" ("DAiLy INDEX)
$0.0 1. SWING SUPPLY AS ►
INCREASES
a `. DECREASES,FROM ` a i LEVELS, NOMINATED
AT LEAST ♦ HOURS PRIOR TO THE START OF DAY.
HUC SHALL PROVIDE HIGHLAND PARK INDUSTRIAL, LLC WITH REAL -
BALANCING, i ON f 3+
V 2110 1 ■ ` k 1 a a
s' • '' ► . ► H I a,
HIGHLAND .INDUSTRIAL, LLC SHALL NOTIFY HU
IN WRITING .DAYS PRIOR ,
THE FIRST DAY OF THE MONTH IN WHICH SUCH
BE UTILIZED THAT c THIRD PARTY HAS BEEN DESIGNATED s
HIGHLAND PARK
aw" INDUSTRIAL'S
'4 AGENT AND SHALL ACT A
AGENT FOR HIGHLAND PARK INDUSTRIAL, LLC FOR PURPOSES
OF NOMINATIONS, BILLING, AND/OR OTHER FUNCTIONS AS
SPECIFIED BY HIGHLAND PARK INDUSTRIAL, LLC. IF HIGHLAND
PARK IND
a OFFr< UTILIZES . AGENT FOR
ANY OR
ALL
PURPOSES,THESE HIGHLAND PARK INDUSTRIAL, AGREES
•
SAID ■ AGENT.DESIGNATION .., x
HIGHLANDIN IN EFFECT
UNTIL PARK INDUSTRIAL,
WRITING AT THE PREVIOUSLY DESIGNATEDAGENT;
LONGER ITSAGENT.
AGENT2. PRIMARY AND SECONDARY CONTACT PERSONS FOR THE
3. TELEPHONE AND OR PRIMARY + r,
AGENTS;SECONDARY CONTACT PERSONS FOR THE AGENT OR
TWENTY-FOUR4. HOUR TELEPHONE NUMBER .
WEEKENDS AND !i !a AGENTS.
HIGHLAND PARK INDUSTRIAL,
MAY O HAVE
^. SERVICES AGREEMENT DIRECTLY
AGENT. HOWEVER,x PARK A
SELECTS THIS OPTION, HIGHLAND PARK INDUSTRIAL,
REMAINS FOR ANY
BILL
RENDERED
—F By HUC. ALL
DEADLINES !" AGREEMENT
TO APPLY, REGARDLESSOF WHETHER HUC's BILL IS SENT
DIRECTLY TO HIGHLAND`t,. INDUSTRIAL,O
HIGHLAND PARK " i. ♦ DESIGNATED AGENT.
x
.eTITS + —
Million
x
'� OF PARTY Cl xIMING I—ORCE FTIAJEURE,AND
SHALL INCLUDE, BUT NOT BE LIMITED TO, ACTS OF GOD,
STRIKES, LOCKOUTS, MATERIAL, LABOR
SHORTAGES,
LANDSLIDES, x - FLOODS,
BREAKAGE : x
CAUSEPIPELINES, FREEZING OF WELLS OR PIPELINES, OR ANY OTHER
OF I KIND, WHETHER SPECIFICALLY
ENUMERATED HEREIN NOT,
CONTROL OF THE +Ri CE i
IF HUC IS UNABLE TO PROVIDE
" SERVICE UNDER
AGREEMENT THIS
+ x +CT .
OBLIGATIONPROVIDE SERVICE UNDER THIS
AGREEMENTSHALLf ! FOR THE DURATION
OF THE ACT OR EVENT. HUC SHALLHIGHLAND
INDUSTRIAL,PARK OF AJEURE EVENT AS
SOON AS REASONABLY PO
+ # x 4
LE BY ANY MEANS
PRACTICABLE,
TELEPHONE OR FACSIMILE,AND SHALL
DETAILSFORCE MAJEURE ACT
r
i EVENT IN
WRITING WITHIN ., REASONABLE AMOUNT OF TIME
THEREAFTER. HUC SHALL
MAJEURE ACT O., EVENT AS AS ! ,:.
LY
POSSIBLE AND SHALL KEEPHIGHLAND PARK INDUSTRIAL,
LLC APPRISED OF THE TIME, DATE,AND CIRCUMSTANCES
UNDERWHEN SERVICE AGREEMENT SHALL
RESTORED. PARK M i
L, LLC IS NOT
REQUIRED PAY ANY AGREEMENTS UNDER THIS
DURING THE TERM OF THE FORCE MAJEURE ACT OR
2. IF HIGHLAND PARK INDUSTRIAL, UNABLESERVICE UNDER THIS AGREEMENT
DUE TO r FOR
MAJEURE ACT OR EVENT, HUC's OBLIGATION TO PROVI
SERVICE UNDER THIS AGREEMENT SHALL 13E SUSPENDE
FOR THE DURATION OF THE ACT OR EVENT. HIGHLAN
PARK INDUSTRIAL, SHALL
FORCE MAJEURE EVENT AS SOON AS REASONAB
POSSIBLE BY PRACTICABLE,
,... LIMITED ; TELE'HONE �' I x '
CONFIRMND SHA
DETAILS FORCE i
WRITINGEVENT IN a REASONABLE
TIME THEREAFTER. HIGHLAND
SHALL WORK TO REMEDY THE FORCE MAJEURE ACT 0
EVENT AS AS REASONABLY POS
+ 'uLAND SHA
APPRISEDKEEP HUC OF THE TIME, DATE, AN
CIRCUMSTANCESxND PAR
aR INDUSTRIAL,
RESUMEWILL UNDER THIS AGREEMENT.
NOT REQUIRED TO PROVIDE SERVICE
UNDER
THI
AGREEMENT OF THE FORCE
ACT OR
SERVICE UNDER THIS AGREEMENT
FUTURE LAWS,ORDERS, REGULATIONS. BY
ANY FEDERAL,
STATE,.o LOCALAUTHORITY HAVING
FORTHOVER THE MATTERS SET
MISCELLANEOUS PROVISIONS
A. DECLARATION O INVALIDITY
IF ANY PROVISION OF THIS AGREEMENT IS DETERMINED TO BE
INVALID, VOID, OR UNENFORCEABLE BY ANY COURT OR OTHER
ENTITY HAVING JURISDICTION, SUCH DETERMINATION SHALL
NOT INVALIDATE, VOID, OR MAKE UNENFORCEABLE ANY OTHER
PROVISION, AGREEMENT OR COVENANT OF THIS AGREEMENT;
AND THE PARTIES AGREE TO NEGOTIATE IN GOOD FAITH A
REPLACEMENT
iF is
PROVISION AND/OR AS
REFLECTSNECESSARY TO ENSURE THAT THE AGREEMENT AS A WHOLE
ORIGINAL PARTIES.
R..
4
.,161 .r waff-el lueown lorguirm .
lm
.. R i
TO CREATE A PARTNERSHIP,
COMPANY, ASSOCIATION R TRUST, FIDUCIARY
RELATIONSHIP
OR PARTNERSHIP BETWEEN THEM. EXCEPT AS EXPRESSLY
PROVIDED HERE] N, NEITHER PARTY SHALL HAVE ANY AUTHORITY
TO ACT FOR OR ASSUME ANY OBLIGATIONS,
RESPONSIBILITIESPARTY.
♦ . fir. �� � � � r
•IY i . _. } 1 ! it J MjMjlIplFA lei:
Y
. ANOTHER
JURISDICTION.
THE PARTIES
x.. ALL BE ENTITLED TO ALL REMEDIES AVAILABLE
AT # TO ENFORCE OR RELIEF
CONNECTION# ` OBLIGATION.
TERMINATIONTERMS OF THis AGREEMENT SHALL BE KEPT CONFIDENTIAL BY
THE PARTIES HERETO FOR TWO YEARS FROM THE EXPIRATION
OR OF AGREEMENT.
IN THE EVENT THAT DISCLOSURE IS REQUIRED a,
GOVERNMENTAL BODY OR APPLICABLE LAW, THE PARTY
SUBJECT TO SUCH RE UIREMENT MAY DISCL# 1
:AM PROTECTITE ORDERS OR SIl'T'IIffltR
RESTRAINTS WITH RESPECT DISCLOSURE AT 77
EXPENSE OF PARTY.
, IIr O
AUTHORITY TO 00AND i PARTY WILL BE BOUND
THIS AGREEMENT SETS FORTH ALL TERMS AGREED UPON BETWEEN TH
PARTIES, AND NO PRIOR ORAL OR WRITTEN AGREEMENTS SHALL BA BINDIN
THIS AGREEMENT SHALL NOT BE ALTERED, AMENDED OR MODIFIED EXCE
AS IN WRITING AND EXECUTED BY BOTH PARTIES. I
I
DATE:
■ -j=lmj:Agqwm
10,
BY:
NAME: Jason Lennartz
wff ommam,
WITNESS: Cyr &4gC-P4�
DATE:
9-INTME1415-�141
HUTCHINSON UTILITIES COMMISSION
^I'xP61Tti'°"
Board Action Form
Agenda Item: Approve Requisition 010227
Presenter: Jeremy
Agenda Item Type:
Time Requested (Minutes): 5
New Business
Attachments: Yes
BACKGROUND/EXPLANATION OFAGENDA ITEM:
As part of HUC's normal Natural Gas system preventive maintenance and inspection
program, corrosion was identified on the steel main that runs underneath school road
bridge. Currently, it is being maintained to appropriate industry standards.
However, in consultation with staff and HUC's consulting firm it is recommended that this
section of main be replaced and removed from the bridge to ensure safety long-term.
HUC is currently working with an engineering firm to initiate the application with the DNR
to bore under the river bottom a new main that will be reconnected to the distribution
system on the south side of school road bridge. The project timeline is estimated
sometime this fall/winter depending on material lead times, permitting, and a boring
company doing the work.
Requisition 010227 is for the materials needed to complete this project. There is a
several month lead time of some of the materials. An additional requisition will be coming
at the appropriate time to do the boring work. This project was not identified in the 2025
Cap Ex project list. However, there should be ample CAPEX budget to accommodate
this project as there is $423K in the 2025 CAP EX Natural Gas division budget.
BOARD ACTION REQUESTED:
Approve Requisition 010227
Fiscal Impact: Estimate Project Cost-$200K
Included in current budget: No Budget Change: No
PROJECT SECTION:
Total Project Cost: Remaining Cost:
HUTCHINSON
UTILITIES
PURCHASE REQUISITION
HUTCHINSON UTILITIES COMMISSION
225 MICHIGAN ST SE
HUTCHINSON, MN 55350
Phone:320-587-4746 Fax:320-587-4721
BORDER STATES ELECTRIC SUPPLY
PO BOX 1450
NW 7235
MINNEAPOLIS, MN 55485
Note
Description:
N.G. Materials for the School Road Boring Project
Date
Requisition No.
04/24/2025
010227
Required by:
Requested by:
jcarter
Item
No.
part No.
Description
Qty
Unit
Due Date
Unit Price
Ext. Amount
NG SCHOOL RD BRIDGE PROJECT
MATERIALS -
1
MFG. PART:
1.00
$43,928.980
$43,928.98
Total: 43, 928.98
Date Printed: 04/24/2025 Requisitioned By: jcarter Page: 1/1
Border States - ABV
11927 53rd Street NE
Albertville MN 55301-3964
Phone: 763-497-6800
HUTCHINSON UTILITIES COMMISSION
175 MICHIGAN ST SE
HUTCHINSON MN 55350-1935
Quote Page: 1 of 2
Quote: 27963062
Sold -To Acct #: 5004
Valid From: 04/22/2025 To: 04/29/2025
PD No: gas quote
PO Date: 04/22/2025
Payment Terms: NET 25TH PROX (31)
Created By: nan I nfrann
Tel No: 612-345-9372
Fax No:
Inco Terms:
PPA PREPAID & ALLOW FREIGHT
Ship -to:
HUTCHINSON UTILITIES COMMISSION
175 MICHIGAN ST SE
HUTCHINSON MN 55350-1935
Cust Item Item
Material Quantity
Price Per
UoM
Value
MFG - Description
000010
2463667 10 EA
88.75 / 1
EA
887.50
CNTP - 360000944 81PS EF COUPLING 4710
Old part #10000361
000020
3516785 2 EA
816.66 / 1
EA
1,633.32
CNTP - 360092737 81PS-11 TF WE 36SLV 4710
000030
3638358 3 EA
90.99 / 1
EA
272.97
PLEX - ELB 81PS-11 4710 BF 90 1007944
000040
3162009 3 EA
932.09 / 1
EA
2,796.27
POLV - 8-89111 POLYVALVE 81PS FP SDR11 4710
000050
3638367 2 EA
117.59 / 1
EA
235.18
PLEX - TEE 81PS-11 4710 BF 1007945
000060
3018293 2 EA
45.74 / 1
EA
91.48
PLEX - RED 81PS-11 X 61PS-11 4710 BF 1007995
000070
3638363 2 EA
39.94 / 1
EA
79.88
PLEX - CAP 81PS-11 4710 BF 1007942
000080
2786561 2 EA
385.88 / 1
EA
771.76
CNTP - 360013973 61PS-11 TF WE W/36SLV 4710
000090
3638345 2 EA
34.20 / 1
EA
68.40
PLEX - ELB 61PS-11 4710 BF 90 1006440
000100
3165032 2 E4
425.93 / 1
EA
851.86
POLV - 6-89111 61PS VALVE BALL FP DR11 4710
000110
2653810 8 EA
62.74 / 1
EA
501.92
CNTP - 360000939 61PS EF COUPLING 4710
Old part #10000359
000120
2865158 1,680 FT
1,709.78 / 100
FT
28,724.30
PLEX - PIPE 81PS X 40 4710 SDR11 YS 1057099
BLACK PIPE WITH YELLOW STRIPE
Border States - ABV
11927 53rd Street NE
Albertville MN 55301-3964
Phone: 763-497-6800
Cust Item Item
000130
Material Quantity
MFG - Description
2970894 480 FT
PLEX - PIPE 61PS X 40 4710 SDR11 YS 1057061
BLACK PIPE WITH YELLOW STIPE
To access Border States Terms and Conditions of Sale, please go to
https://www.borderstates.com
The quoted sales tax is an estimate only based upon the information
provided in this quote and will be finalized at the time of Invoice
based upon the material purchased, quantity purchased, and delivery
location.
Shipping and handling fees in this quote are an estimate only and will
be finalized at the time of Invoice.
Quote Page: 2 of 2
Quote: 27963062
Sold -to Acct #: 5004
Valid From: 04/22/2025 To: 04/29/2025
Price Per UoM
872.56 / 100 FT
Total $
State Tax $
6.875
% 2,825.85
County Tax $
0.000
%
0.00
Local Tax $
0.000
%
0.00
Other Tax1 $
0.000
%
0.00
Other Tax2 $
0.000
%
0.00
Other Tax3 $
0.000
%
0.00
Tax Subtotal $
6.875
%
Net Amount $
III clerical errors contained herein are subject to correction. In the event of any cost or price
icreases from manufacturers or other suppliers, caused by, but not limited to, currency fluctuation:
aw material or labor prices, fuel or transportation cost increases, and any import tariffs, taxes,
ses, or surcharges, Border States reserves the exclusive right to change its pricing at the time of
hipping and will provide notice of any such change to its customers prior to costs being incurred.
Value
4.188.29
41,103.13
2,825.85
43,928.98
HUTCHINSON UTILITIES COMMISSION
^I'xP61Tti'°"
Board Action Form
Agenda Item: Approve Req 010225 Phase 3 Tuck Pointing with additional brick repair Plant 1
Presenter: Mike Gabrielson
Agenda Item Type:
Time Requested (Minutes): 5
New Business
Attachments: Yes
BACKGROUND/EXPLANATION OFAGENDA ITEM:
This is the 3rd and final phase of the tuck pointing project which will be addressing the
precast building on the east side of the plant. This original 3rd phase of the project was a
CAPX 2025 project.
Additional scope of work to this phase is needed after removing units 3 and 4 exhaust
stacks. The brick that was behind those units is in poor condition and needs to be
repaired/replaced. This additional work was not part of the CAPX for 2025.
There was $40,000 budgeted for the original phase 3 scope of work. To complete this
extra work an additional $61,550 needs to be added to the original 3rd phase scope of
work bringing the total 3rd phase of the project to $101,550. The CAPX project list will be
adjusted accordingly to accommodate this additional scope of work to complete the tuck
pointing at the downtown plant.
BOARD ACTION REQUESTED:
Approve Req 010225 Phase 3 Tuck Pointing with additional brick repair Plant 1
Fiscal Impact: $101,550
Included in current budget: Yes El Budget Change: Yes
PROJECT SECTION:
Total Project Cost: Remaining Cost:
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
AMERICAN MASONRY
7701 EAST RIVER ROAD
FRIDLEY, MN 55432
Note
Description:
Phase 3 Tuck Pointing
PURCHASE REQUISITION
HUTCHINSON UTILITIES COMMISSION
225 MICHIGAN ST SE
HUTCHINSON, MN 55350
Phone:320-587-4746 Fax:320-587-4721
Date
Requisition No.
04/24/2025
010225
Required by:
Requested by:
mgabrielson
Item
No.
part No.
Description
Qty
Unit
Due Date
Unit Price
Ext. Amount
PHASE 3 REPAIR -
MFG. PART:
1
1.00
EA
06/11/2025
$38,400.000
$38,400.00
ADDITIONAL BRICK REPAIR U3 AND U4
STACK -
2
MFG. PART:
1.00
EA
06/11 /2025
$63,150.000
$63,150.00
Total: 101,550.00
Date Printed: 04/24/2025 Requisitioned By: mgabrielson Page: 1/1
l�l�
�1Ima:
" Am
A Mkµ I A NA, 0 "Y
Rr"' rr.uAl Ar I N
7701 East River Road Fridley, MN 55432 763-502-1400 Fax 763-502-1400 WWW.americanmasonry.net
March 25, 2025
Mr. Mike Gabrielson
Production Manager
225 Michigan Street SE
Hutchinson, MN 55350
S0
Dear Mike,
Thank you for contacting American Masonry Restoration to provide a proposal for your
brick infill repairs. After reviewing the condition on site with you yesterday we have
prepared a proposal for your review.
Please contact me with any questions that you may have regarding the items listed
below.
Sincerely,
AMERICAN MASONRY RESTORATION
Dustin R. Sly
Exterior Building
Maintenance & Repair
Repointing
Caulking
Brick/Stone Repair
Exterior Painting
Chemical Cleaning
��i➢IUIOIN)IAUIIIUUINUI>!<91�1t1�➢1�jUy�°�A�t�u���l��r:��
7701 East River Road Fridley, MN 55432 763-502-1400 Fax 763-502-1400 WWW.americanmasonry.net
Date: March 25, 2025
Presented To: Mr. Mike Gabrielson
Project: Masonry Repair Proposal Brick Infills
Disclosure Statement
The data contained herein shall not be duplicated by
anyone without prior written permission of American
Masonry Restoration and shall not be duplicated, used,
or disclosed in whole or in part for any purpose other
than evaluation by the party intended.
Exterior Building
Maintenance & Repair
Repainting
Caulking
Brick/Stone Repair
Exterior Painting
Chemical Cleaning
Hutchinson Power Plant
Repair Key-:
iiiiiiiiiiiiiiiiiiiiiillillilillillilllliiiiiiiiiiiiiiiiiiiiiiiiii Additional Repair Area after removal of mechanical equipment.
Work remaining from phased proposal for this year (2025). Precast Building.
7701 ["ast River Road, [''ri(fley, MN 55432 763 502 1400 [�Ak 763 502 1300
Hutchinson Power Plant
Base Bid: Cleaning of surfaces:
Repointing of surfaces:
Infill surfaces:
Remove block and repair jambs.
7701 ["ast River Road, [''ri(fley, MN 55432 763 502 1400 [�Ak 763 502 1300
Hutchinson Power Plant
Alternate Bid- Remove red brick/concrete and infill with yellow brick:
Repointing of surfaces:
Infill surfaces:
Remove block and repair jambs-
7701 ["ast River Road, [''ri(fley, MN 55432 763 502 1400 [�Ak 763 502 1300
UII N��NNV�v�ld�!�titiUll^'�UW��w�mom�
uJ� �kU�UI�IIJ011���I1�IN!�f��y1�i��ynV9U�'l��NiY�uK,r�m=��
Hutchinson Power Plant
Date: May 25, 2025
To: Mr. Mike Gabrielson
Project: Hutchinson Powerplant Exterior Masonry Repairs
Architect: N/A
Addenda: N/A
American Masonry Restoration proposes to furnish all the necessary materials and to provide
skilled labor to perform the following scope of work. Prices listed include standard contractors
liability insurance, compliance with all OSHA regulations, all labor, materials and equipment for
our scope of work. We reserve the right to withdraw this proposal if it is not accepted within thirty
days. Our payment terms are net 10 days on all progress invoices. Interest in the amount of 1 '/
percent will be charged on all past due balances.
Additional Brick Repairs
Option 1, Base Bid: $36,205.00
Option 2, Alternate Bid: $63,150.00
Bids are individual and should not be combined.
Phase 3 scope of repair work includes (Precast Building_
1. The precast building will have all exterior sealants replaced, door perimeter sealants replaced,
brick repointing allowance of up to 50 LF and a concrete patching allowance to replace
deteriorated mortar patches.
Total Cost: $38,400.00 Phase 3 (no changes from previous proposal)
Assumptions: Staging area will be provided for equipment and material. Work is to be
performed 2025, access to water and power will be needed at no charge.
Exclusions: Removal or disposal of hazardous material, building permits, bonds, sheet
metal work, interior work, mechanical or electrical removal, protection or installation, cold
weather conditions, overtime or premium work hours and any item not specifically listed
above.
AMERICAN MASONRYRESTORATION
Dustin R. Sly