11-29-2017 HUCCPHUTCHINSON UTILITIES COMMISSION
AGENDA
REGULAR MEETING
November 29, 2017
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. Legal
d. General Manager
6. POLICIES
a. Review Policies
i. Appendix A — Acknowledgement
ii. Appendix B — New Employee Acknowledgement
iii. Appendix C — Temporary Employee Acknowledgement
iv. Appendix D —Acknowledgement
v. Landlord Acknowledgement
vi. Inserts with Utility Bills
vii. Financial Reserve Policy
b. Approve Changes
i. After Hours Reconnection Policy
7. UNFINISHED BUSINESS
a. Update on Pack Gas Discussions
8. NEW BUSINESS
a. Approve Charge-offs
b. Discuss 2018 Budget
C. Discuss date for Performance Review of Hutchinson Utilities
Commission General Manager
d. Declare Employee Recognition Dinner on December 8, 2017 as an
Open Meeting
e. Approve Rescheduling the December Regular Commission Meeting to
Wednesday, December 20, 2017
9. ADJOURN
MINUTES
Regular Meeting — Hutchinson Utilities Commission
Wednesday, October 25, 2017
Call to Order — 3:00 p.m.
President Monty Morrow called the meeting to order at 3:00 p.m. Members present:
President Monty Morrow; Vice President Anthony Hanson; Commissioner Robert
Wendorff; and Commissioner Don Martinez. Secretary Mark Girard was absent.
Others present: General Manager Jeremy Carter; Attorney Marc Sebora.
1. Conflict of Interest
There were no conflicts of interest noted.
2. Approve Consent Agenda
a. Approve Minutes
b. Ratify Payment of Bills
Motion by Wendorff, second by Martinez to approve the Consent Agenda.
Motion carried unanimously.
3. Approve Financial Statements
General Manager Carter presented the financial statements. Mr. Carted noted that
everything is tracking, as we should. Rates are starting to go down for fall. Would
like to highlight the financial ratios for individual Electric and Gas sheets are now
accurate and up to date for 2017, this is something new. Typically, those individual
divisions ratio are not separated out until year-end but because HUC is running
separate balance sheets with the new software conversion this is possible.
Jared Martig mentioned cash went down in September, and operationally will
for next 2 months due to the payment of bonds. Otherwise similar as years
past.
Motion by Hanson, second by Martinez to approve the financial statements.
Motion carried unanimously.
4. Open Forum -none
5. Communication
a. City Administrator— Matt Jaunich
i. Mr. Jaunich communicated that the City is in the middle of the budget
process.
ii. Construction on the Hotel to start at the end of November. Finishing
the last part of the road today.
iii. Enterprise Building to be completed by the end of the month. Two
tenants are already in.
iv. High Field Apartments, 1st phase will be open for November.
1
v. Century Court dirt work will be going on this fall.
b. Divisions
i. Dan Lang, Engineering Services Manager —Absent
ii. Dave Hunstad, Electric Transmission/Distribution Manager- working on
hotel site this week. Should be wrapping up on third apartment for High
Field and Hotel.
iii. Randy Blake, Production Manager — nothing to report
iv. John Webster, Natural Gas Division Manager- There is a customer down
south that has exceeded capacity by over 100%. A meeting is happening
next week to see how to remedy the problem.
v. Jared Martig, Financial Manager —Electric/Gas Bills went out without
problems. Tom Kloss was able to help with the bandwidth of the file.
Customers have at least 10 days to pay.
c. General Manager — Jeremy Carter
i. Will be attending the annual area MRES meeting in Alexander with Jared
on Thursday. Will then need to get numbers in the budget.
ii. Had a preliminary meeting this morning with UFS on the Cost of Study
service. Need to work on some additional information and then get the
commissioners involved so we can move forward.
iii. Working on Final budget for November meeting. Need to adjust power
supply and update transmission cost- Dan & I are working on that. We are
waiting for clarification.
iv. Finalizing Health Insurance. Had a meeting with union representation.
We are looking between Health Partners and Medica. Hoping to have an
insurance decision wrapped up by Mid November.
v. Working on CIP plan next couple of weeks.
vi. Sent info on Pilot information- looking for feedback. Please let me know
what you think of resolution language and financial impact will be before I
send to Matt. I know you may want to wait on Cost of Service study but
need to try to move forward.
Commissioner Hanson inquired on when the budget should be approved.
General Manager Carter explained he was thinking November have
budget presentation, than have 2-3 weeks to look over and would like to
approve in December. This is consistent with years past.
vii.For the upcoming Commission meetings, November date works well for
everyone. For December, looks like we need to move up a week to
December 20th
viii. If Cost of Service Study is ready to go for November meeting then you
could consider discussing at the monthly meeting or at a workshop on a
different day. The budget and Cost of Service study could be two lengthy
topics. Not seeing anything stand out for the budget in 2018. What we
see in 2017 will be fairly consistent to 2018. Will know more at the end of
the week.
d. Legal — Marc Sebora —Working on generator contracts.
6. Policies
a. Review Policies
i. Investment Policy
ii. Disconnection of Residential Services by Utilities
iii. Disconnection of Commercial Services by Utilities
iv. Health & Safety
v. Accidents & Injuries
vi. Unsafe Conditions or Practices
vii. Employee Right -To -Know
b. Approve Changes
i. Budget Payment Plan —as noted
ii. Investment policy —Commission Hanson asked if everything looked good
and if auditors have looked at investment policy. General Manager Carter
said everything looks good.
iii. Explanation of Billing Procedure- as noted
Motion by Martinez, second by Wendorff, to approve the policy changes as
recommended. Motion carried unanimously.
7. Unfinished Business
a. Update of Pack Gas Discussions
Attorney Marc Sebora noted that he called the attorney three times last month and
has not had a response.
Commissioner Hanson commented that this sounds like this is all we can do.
Attorney Sebora agreed.
8. New Business
a. Approval of Rollover of Northern Natural Gas Transportation Contract #21279
John Webster, Natural Gas Division Manager communicated that HUC built
pipeline in 2003-2004; we did maintain backup capacity supply on Northern
Natural Gas. We have two contracts with Northern Natural Gas. One is for 8000
d/day we would like to lower it to 100 d/day. This is just enough to keep the
station going. We would pay approximately $11 k a year, which is just enough to
keep it there. If something were to happen to our station, we would have
Northern Natural gas as a backup and would have to buy extra capacity to get us
through. I feel it is better to pay for limited time instead of paying for unused
capacity. Right now is the time to renew for another 5 years, they require 1 year
in advance.
Commissioner Martinez inquired if we renew this we maintain capacity of another
source in case something were to happen to our line and we would be without
gas. Therefore, even if we pay for penalties I feel this a cheap insurance policy.
President Monty asked if this is budgeted. Mr. Webster replied it is.
K
Motion by Hanson, second by Wendorff, to approve the Rollover of Northern
Natural Gas Transportation Contract #21279. Motion carried unanimously.
b. Approval of Generator Contract
Mr. Carter noted this is the final step in approving the generator contract. Since
we awarded the bid, we have spent time working on the contract language,
shipment dates, insurance threshold, critical and spare parts, and how things are
going to run. None of the things we were working on had to do with the cost but
with the design. We have been doing a lot of back and forth conversations,
Caterpillar has accepted the final language and we can now proceed moving
forward. Both generator contract bids had a 60 -day lock, but we had to talk
through all the negotiations. We anticipated we would have the contracts in place
and before the commission to sign, however we were not able to meet the
deadline and now with the new exchange rate, we went from $8.8M to $9.1 M,
which is a $286K increase. Overall, everything went very well, there was a lot of
conversations and a lot of give and take. Caterpillar has had engineers come
out; they are able to work around what we have here and everyone is eager to
move forward. This is a very lengthy contract with lots of data. Jim Booty went
through all of the technical data, and they can supply what we need. Final step is
execution of the contract. In the spring, we will need to go out and get bids for
electric, mechanical, and civil. Will still have engines by late summer early fall.
Bonds are all set, should receive money by end of month. Mr. Carter asked the
Commission if they had any questions.
Commissioner Hanson asked Mr. Sebora if he was good with the contract. Mr.
Sebora replied that he is. We have gone through all of this many times and
thanked Randy Blake for his knowledge and the time that he has put into this.
Commissioner Hanson asked Mr. Blake if he was comfortable on his side. Mr.
Blake verified that he is. The engineers are very intelligent people. They brought
a team of four from Germany and spent 38 hours here. They assured us they
can make it work. There was a struggle with document but it should be a good
project. Mr. Blake also thanked Mr. Carter and Mr. Sebora. This takes many
hands with the length of document.
President Monty asked Mr. Jaunich if he had any questions. Mr. Jaunich replied
that the City Council is supportive.
Commissioner Wendorff inquired if we are still on the same timeline. Mr. Carter
replied that we are.
Commissioner Hanson noted whatever we can do to stay in the contract with
Rice Lake and stay in the parameters. Mr. Carter assured him we are.
Motion by Hanson, second by Martinez, to approve the Generator Contract.
4
Motion carried unanimously.
At this time, Commission Martinez inquired how the Open House went. Mr. Carter
noted that it went well. We had 574 people come through.
Commissioner Hanson asked if we had done something different this year. Mr.
Carter replied that we did not. This year there was more of a steady stream
throughout the entire night.
Commissioner Hanson noted this is a good thing for community and thanked the
staff for all their work.
9. Adjourn
There being no further business, a motion was made by Martinez, second by
Wendorff, to adjourn the meeting at 3:36 p.m. Motion carried unanimously.
ATTEST:
Monty Morrow, President
Mark Girard, Secretary
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HUTCHINSON UTILITIES COMMISSION
COMBINED DIVISIONS
FINANCIAL REPORT FOR OCTOBER, 2017
Salaries & Benefits
Purchased Commodities
Transmission
Generator Fuel/Chem.
Depreciation
Transfers (Elect./City)
Operating Expense
Debt Interest
TOTAL EXPENSES
NET PROFIT/(LOSS)
VIII
83.3% of Year Comp.
2017
2016
Di
% Chnq
2017
2016
pi .
Combined Division
78.3%
8.4%
$ 734,878
102.9%
0.7%
$ 651,700
83.3%
24.3%
Customer Revenue
$
2,742,589
$ 2,645,948
$ 96,640
3.7%
$ 28,863,919
$ 28,471,107
$ 392,811
Sales for Resale
$
177,127
$ 153,090
$ 24,037
15.7%
$ 1,808,418
$ 1,605,141
$ 203,277
NU Transportation
$
88,601
$ 82,786
$ 5,815
7.0%
$ 755,878
$ 697,473
$ 58,404
Electric Division Transfer
$
54,308
$ 53,931
$ 378
0.7%
$ 543,083
$ 539,305
$ 3,778
Other Revenues
$
117,828
$ 49,357
$ 68,470
138.7%
$ 639,077
$ 514,050
$ 125,027
Interest Income
$
12,916
$ 4,652
$ 8,264
177.7%
$ 114,794
$ 47,313
$ 67,482
TOTAL REVENUES
$
3,193,368
$ 2,989,764
$ 203,604
6.8%
$ 32,725,168
$ 31,874,390
$ 850,778
Salaries & Benefits
Purchased Commodities
Transmission
Generator Fuel/Chem.
Depreciation
Transfers (Elect./City)
Operating Expense
Debt Interest
TOTAL EXPENSES
NET PROFIT/(LOSS)
VIII
83.3% of Year Comp.
Chnq
Full Yr Bud
% of Bud
1.4%
$ 36,743,052
78.6%
12.7%
$ 2,310,110
78.3%
8.4%
$ 734,878
102.9%
0.7%
$ 651,700
83.3%
24.3%
$ 498,808
128.1%
142.6%
$ 100,000
114.8%
2.7%1 $ 41,038,548 79.7%
$ 466,339
$ 449,523
$ 16,816
3.74%
$ 4,617,338
$ 4,781,912
$ (164,574)
(3.4%)
$ 6,005,227
76.9%
$ 1,530,266
$ 1,385,238
$ 145,028
10.5%
$ 16,314,026
$ 15,659,317
$ 654,709
4.2%
$ 20,990,267
77.7%
$ 201,665
$ 198,688
$ 2,977
1.5%
$ 2,126,266
$ 1,962,896
$ 163,370
8.3%
$ 2,550,000
83.4%
$ 42,932
$ 49,193
$ (6,260)
(12.7%)
$ 812,435
$ 1,035,581
$ (223,146)
(21.5%)
$ 1,249,801
65.0%
$ 317,333
$ 311,526
$ 5,807
1.9%
$ 3,173,334
$ 3,130,000
$ 43,334
1.4%
$ 3,808,000
83.3%
$ 154,003
$ 150,657
$ 3,345
2.2%
$ 1,540,025
$ 1,494,528
$ 45,497
3.0%
$ 1,700,647
90.6%
$ 188,477
$ 140,775
$ 47,702
33.9%
$ 1,841,071
$ 1,635,190
$ 205,881
12.6%
$ 2,583,006
71.3%
$ 61,258
$ 67,676
$ (6,418)
(9.5%)
$ 631,699
$ 676,761
$ (45,061)
6.7%
$ 760,588
83.1%
$ 2,962,274
$ 2,753,275
$ 208,998
7.6%
$ 31,056,194
$ 30,376,185
$ 680,010
2.2%
$ 39,647,536
78.3%
$ 231,094
$ 236,489
$ (5,394)
(2.3%)
$ 1,668,974
$ 1,498,205
$ 170,769
11.40%
$ 1,391,013
120.0%
2017
HUC
Budget
Target
30.0%
10NNNNNNNN�
4.5%hP��������llNllNldl
October
October
YTD
YTD
2017
2016
Change
2017
2016
Change
Gross Margin %
35.3%
37.4%
-2.2%
32.6%
33.6%
-1.0%
Operating Income Per Revenue $ (%)
5.9%
9.3%
-3.4%
5.3%
5.9%
-0.6%
Net Income Per Revenue $ (%):
7.2%
7.9%
-0.7%
5.1%
4.7%
0.4%
2017
HUC
Budget
Target
30.0%
10NNNNNNNN�
4.5%hP��������llNllNldl
3.4%
HUTCHINSON UTILITIES COMMISSION
ELECTRIC DIVISION
FINANCIAL REPORT FOR OCTOBER, 2017
Salaries & Benefits
Purchased Power
Transmission
Generator Fuel/Chem.
Depreciation
Transfers (Elect./City)
Operating Expense
Debt Interest
TOTAL EXPENSES
NET PROFIT/(LOSS)
$ 364,337
83.3% of Year Comp.
346,631
2017
2016
$ 3,617,444
2E
%Chna
2017
2016
$ 4,727,135
2E
%Chna
Full Yr Bud
%of Bud
Electric Division
18.0%
$ 11,983,283
$ 11,434,479
$
548,804
4.8%
$ 14,208,043
84.3%
$ 201,665
$
198,688
$ 2,977
Customer Revenue
$ 2,085,405
$ 1,999,783
$
85,622
4.3%
$ 21,333,920
$ 21,182,234
$
151,686
0.7%
$ 25,185,461
84.7%
Sales for Resale
$ 177,127
$ 153,090
$
24,037
15.7%
$ 1,808,418
$ 1,605,141
$
203,277
12.7%
$ 2,310,110
78.3%
Other Revenues
$ 91,944
$ 24,634
$
67,310
273.2%
$ 399,804
$ 303,655
$
96,149
31.7%
$ 280,200
142.7%
Interest Income
$ 6,458
$ 2,326
$
4,132
177.7%
$ 57,397
$ 23,656
$
33,741
142.6%
$ 50,000
114.8%
TOTAL REVENUES
$ 2,360,933
$ 2,179,833
$
181,100
8.3%
$ 23,599,539
$ 23,114,687
$
484,852
2.1%
$ 27,825,771
84.8%
Salaries & Benefits
Purchased Power
Transmission
Generator Fuel/Chem.
Depreciation
Transfers (Elect./City)
Operating Expense
Debt Interest
TOTAL EXPENSES
NET PROFIT/(LOSS)
$ 364,337
$
346,631
$ 17,706
5.1%
$ 3,617,444
$ 3,749,089
$
(131,644)
(3.5%)
$ 4,727,135
76.5%
$ 1,162,097
$
985,056
$ 177,040
18.0%
$ 11,983,283
$ 11,434,479
$
548,804
4.8%
$ 14,208,043
84.3%
$ 201,665
$
198,688
$ 2,977
1.5%
$ 2,126,266
$ 1,962,896
$
163,370
8.3%
$ 2,550,000
83.4%
$ 42,932
$
49,193
$ (6,260)
(12.7%)
$ 812,435
$ 1,035,581
$
(223,146)
(21.5%)
$ 1,249,801
65.0%
$ 233,333
$
225,000
$ 8,333
3.7%
$ 2,333,334
$ 2,250,000
$
83,334
3.7%
$ 2,800,000
83.3%
$ 123,408
$
116,803
$ 6,605
5.7%
$ 1,234,083
$ 1,160,200
$
73,883
6.4%
$ 1,333,516
92.5%
$ 133,540
$
93,097
$ 40,443
43.4%
$ 1,296,516
$ 1,134,612
$
161,904
14.3%
$ 1,746,330
74.2%
$
$
2,551
$ (2,551)
(100.0%)
$ 19,116
$ 25,511
$
(6,395)
25.1%
$ 25,488
75.0%
$ 2,261,312
$ 2,017,018
$ 244,293
12.1%
$ 23,422,476
$ 22,752,366
$
670,109
2.9%
$ 28,640,313
81.8%
$ 99,621
$
162,815
$ (63,193)
(38.8%)
$ 177,063
$ 362,320
$
(185,257)
(51.1%)
$ (814,542)
(21.7%)
The Electric division in October 2017 had a net profit decline of $63,193. Increased Customer Revenue was mainly due to a significant power cost
adjustment in October because of a significant reduction in kwhr's sold and increased MISO costs.
Sales for Resale of $177,127 consisted of $16,604 in market sales, $34,400 in the monthly tolling fee from Transalta, $30,123 in energy sales to Transalta,
and $96,000 in capacity sales to SMMPA. October 2016 Sales for Resale of $153,090 consisted of $17,619 in market sales, $34,400 in monthly tolling
fees from Transalta, $34,571 in Transalta energy sales, and $66,500 in capacity sales to SMMPA. October 2015 Sales for Resale of $94,898 consisted
of $769 market sales, $34,400 in Transalta tolling fees, $17,729 in Transalta energy sales, and capacity sales to SMMPA for $42,000.
Overall Purchased Power increased by $177,041. MRES purchases increased by $46,804 and market purchases/MISO costs increased by $130,237.
The power cost adjustment for October 2017 was $.0096/kwhr bringing in an additional $212,115 of revenue for the month and $1,512,714 for the
year. Last year's power cost adjustments through October of 2016 generated $687,476 in additional revenue. Total PCA collections through
October 2015 were $385,433
83.3% of Year Comp.
2017
2016
2E
%Chna
2017
2016
2E
%Chna
Full Yr Bud
%of Bud
Electric Division
Residential 3,471,301
3,808,965
(337,664)
(8.86%)
40,930,402
42,534,860
(1,604,458)
(3.77%)
50,432,797
81.2%
All Electric 136,891
138,739
(1,848)
(1.33%)
1,824,663
1,889,655
(64,992)
(3.44%)
2,611,705
69.9%
Small General 1,331,147
1,441,239
(110,092)
(7.64%)
14,829,322
14,937,003
(107,681)
(0.72%)
17,085,853
86.8%
Large General 6,154,995
6,223,794
(68,799)
(1.11%)
62,909,380
62,002,522
906,858
1.46%
79,262,499
79.4%
Industrial 11,249,000
12,098,000
(849,000)
(7.02%)
114,668,000
118,998,000
(4,330,000)
(3.64%)
134,707,856
85.1%
Total KWH Sold 22,343,334
23,710,737
(1,367,403)
(5.77%)
235,161,767
240,362,040
(5,200,273)
(2.16%)
284,100,710
82.8%
71
October
October
YTD
YTD
2017
HUC
2017
2016
Change
2017
2016
Change
Budget
Target
Gross Margin %
28.9%
33.8%
-4.9%
26.1%
27.8%
-1.7°%
22.5%
Operating Income Per Revenue $ (%)
0.7%
7.5%
-6.8%
-0.5%
1.3%
-1.8%
-3.0%
0%-5%
Net Income Per Revenue $ (%):
4.2%
7.5%
-3.2%
0.8%
1.6%
-0.8%
-2.9°%
Customer Revenue per KWH:
$0.0933
$0.0843
$0.0090
$0.0903
$0.0877
$0.0026
$0.0881
Total Power Supply Exp. per KWH:
$0.0724
$0.0608
$0.0117
$0.0732
$0.0692
$0.0040
$0.0758
The Electric division in October 2017 had a net profit decline of $63,193. Increased Customer Revenue was mainly due to a significant power cost
adjustment in October because of a significant reduction in kwhr's sold and increased MISO costs.
Sales for Resale of $177,127 consisted of $16,604 in market sales, $34,400 in the monthly tolling fee from Transalta, $30,123 in energy sales to Transalta,
and $96,000 in capacity sales to SMMPA. October 2016 Sales for Resale of $153,090 consisted of $17,619 in market sales, $34,400 in monthly tolling
fees from Transalta, $34,571 in Transalta energy sales, and $66,500 in capacity sales to SMMPA. October 2015 Sales for Resale of $94,898 consisted
of $769 market sales, $34,400 in Transalta tolling fees, $17,729 in Transalta energy sales, and capacity sales to SMMPA for $42,000.
Overall Purchased Power increased by $177,041. MRES purchases increased by $46,804 and market purchases/MISO costs increased by $130,237.
The power cost adjustment for October 2017 was $.0096/kwhr bringing in an additional $212,115 of revenue for the month and $1,512,714 for the
year. Last year's power cost adjustments through October of 2016 generated $687,476 in additional revenue. Total PCA collections through
October 2015 were $385,433
HUTCHINSON UTILITIES COMMISSION
GAS DIVISION
FINANCIAL REPORT FOR OCTOBER, 2017
Salaries & Benefits
$
2017
2016
2E
Gas Division
$
368,169
$ 400,181
$ (32,012)
Customer Revenue
$
657,184
$ 646,166
$ 11,018
Transportation
$
88,601
$ 82,786
$ 5,815
Electric Div. Transfer
$
54,308
$ 53,931
$ 378
Other Revenues
$
25,884
$ 24,723
$ 1,160
Interest Income
$
6,458
$ 2,326
$ 4,132
TOTAL REVENUES
$
832,435
$ 809,931
$ 22,503
Salaries & Benefits
$
102,003
$ 102,892
$ (890)
Purchased Gas
$
368,169
$ 400,181
$ (32,012)
Operating Expense
$
54,937
$ 47,678
$ 7,259
Depreciation
$
84,000
$ 86,526
$ (2,526)
Transfers (City)
$
30,594
$ 33,854
$ (3,260)
Debt Interest
$
61,258
$ 65,125
$ (3,867)
TOTAL EXPENSES
$
700,962
$ 736,257
$ (35,295)
NET PROFIT/(LOSS)
$
131,473
$ 73,674
$ 57,799
(0.9%)
83.3% of Year Comp.
%Chng
2017
2016
(3.2%)
2E
%Chna
Full Yr Bud
%of Bud
1.7%
$ 7,529,999
$ 7,288,873
$
241,126
3.3%
$ 11,557,591
65.2%
7.0%
$ 755,878
$ 697,473
$
58,404
8.4%
$ 734,878
102.9%
0.7%
$ 543,083
$ 539,305
$
3,778
0.7%
$ 651,700
83.3%
4.7%
$ 239,273
$ 210,395
$
28,878
13.7%
$ 218,608
109.5%
177.7%
$ 57,397
$ 23,656
$
33,741
142.6%
$ 50,000
114.8%
2.8%
$ 9,125,629
$ 8,759,703
$
365,926
4.2%
$ 13,212,777
69.1%
(0.9%)
$ 999,894
$ 1,032,824
$
(32,930)
(3.2%)
$ 1,278,092
(8.0%)
$ 4,330,744
$ 4,224,839
$
105,905
2.5%
$ 6,782,224
15.2%
$ 544,555
$ 500,578
$
43,977
8.8%
$ 836,676
(2.9%)
$ 840,000
$ 880,000
$
(40,000)
(4.5%)
$ 1,008,000
(9.6%)
$ 305,943
$ 334,328
$
(28,386)
(8.5%)
$ 367,131
0.0%
$ 612,584
$ 651,250
$
(38,667)
JL22L
$ 735,100
(4.8%)
$ 7,633,718
$ 7,623,818
$
9,900
0.1%
$ 11,007,223
78.5%
$ 1,491,910
$ 1,135,885
$
356,026
31.3%
$ 2,205,554
78.2%
63.9%
65.1%
83.3%
83.3%
83.3%
69.4%
67.6%
f
%rr
o
83.36 of Year Comp.
2017
2016
Di
%Chnq
2017
2016
Di
%Chnq
Full Yr Bud
%of Bud
Gas Division
Budget Target
Gross Margin %
53.2%
47.3%
5.9%
49.9%
49.4%
0.5%
46.2% IIIIIIIIIIIIIIIIIIIIIIII ����
Operating Income Per Revenue $ (%)
Residential
22,298,558
20,096,794
2,201,764
10.96%
272,693,055
272,527,865
165,190
0.06%
449,582,000
60.7%
Commercial
19,685,111
15,626,449
4,058,662
25.97%
226,966,967
207,710,658
19,256,309
9.27%
420,183,000
54.0%
Industrial
69,371,631
64,015,406
5,356,225
8.37%
674,121,822
626,029,991
48,091,831
7.68%
786,836,000
85.7%
Total CF Sold
111,355,300
99,738,649
11,616,651
11.65%
1,173,781,844
1,106,268,514
67,513,330
6.10%1
1,656,601,000
70.9%
Net Profit for October 2017 increased by $57,799 in the gas division over October 2016.
The fuel credit adjustment for October 2017 was $1.50528/MCF providing credits to the customers of $71,013 for the month and $523,090 for the year.
Fuel credit adjustments totalled $44,625 through October of 2016.
October
October
YTD
YTD
2017 HUC
2017
2016
Change
2017
2016
Change
Budget Target
Gross Margin %
53.2%
47.3%
5.9%
49.9%
49.4%
0.5%
46.2% IIIIIIIIIIIIIIIIIIIIIIII ����
Operating Income Per Revenue $ (%)
20.6%
14.3%
6.3%
20.6%
18.2%
2.4%
20.6%
Net Income Per Revenue $ (%):
16.4%
9.4%
7.0%
16.9%
13.3%
3.6%
�pyN�NNpNp�p�p�p�N�
17.0% ��MflIII�IIIIIIIIIIppIIppIIppIIppIIpp
Contracted Customer Rev. per CF:
$0.0036
$0.0037
-$0.0001
$0.0038
$0.0034
$0.0004
$0.0041 �NIIIIIIIIII
Customer Revenue per CF:
$0.0097
$0.0115
-$0.0018
$0.0100
$0.0108
-$0.0008
$0.0096
Total Power Supply Exp. per CF:
$0.0034
$0.0041
($0.0007)
$0.0038
$0.0039
($0.0001)
$0.0042
Net Profit for October 2017 increased by $57,799 in the gas division over October 2016.
The fuel credit adjustment for October 2017 was $1.50528/MCF providing credits to the customers of $71,013 for the month and $523,090 for the year.
Fuel credit adjustments totalled $44,625 through October of 2016.
Current Assets
UnrestrictedlUndesignated Cash
Cash
Petty Cash
Designated Cash
Capital Expenditures - Current Yr
Payment in Lieu of Taxes
Rate Stabilization - Electric
Rate Stabiliation - Gas
Catastrophic Funds
Restricted Cash
Bond Interest Payment 2003
Bond Interest Payment 2012
Debt Service Reserve Funds
Total Current Assets
Receivables
Accounts (net of uncollectible allowances)
Interest
Total Receivables
Other Assets
Inventory
Prepaid Expenses
Sales Tax Receivable
Deferred Outflows - Electric
Deferred Outflows - Gas
Total Other Assets
HUTCHINSON UTILITIES COMMISSION
BALANCE SHEET - CONSOLIDATED
OCTOBER 31, 2017
Electric Gas Total Total
Division Division 2017 2016
Net Change
Total (YTD)
6,227,617.20
4,779,354.48
11,006,971.68
11,540,137.61
(533,165.93)
680.00
170.00
850.00
850.00
-
113,365.34
1,261,751.93
1,375,117.27
688,079.90
687,037.37
829,200.00
367,131.00
1,196,331.00
1,305,256.00
(108,925.00)
314,539.41
-
314,539.41
456,183.58
(141,644.17)
-
646,058.37
646,058.37
572,227.12
73,831.25
400,000.00
100,000.00
500,000.00
500,000.00
-
137,946.88
-
137,946.88
138,532.95
(586.07)
-
1,955,100.04
1,955,100.04
1,584,333.37
370,766.67
-
2,188,694.02
2,188,694.02
2,188,694.02
-
8,023,348.83
11,298,259.84
19,321,608.67
18,974,294.55
347,314.12
2,003,064.08
22,224.58
2,025,288.66
1,216,053.90
15,665.80
174,847.04
1,746,060.00
3,152,626.74
740,105.51
9,191.09
2,743,169.59
31,415.67
2,557,381.55
-
185,788.04
31,415.67
749,296.60
2,774,585.26
2,557,381.55
217,203.71
411,692.87
1,627,746.77
1,473,970.94
153,775.83
20,203.84
35,869.64
(17,356.44)
53,226.08
-
174,847.04
143,146.16
31,700.88
-
1,746,060.00
388,200.00
1,357,860.00
582,020.00
582,020.00
129,400.00
452,620.00
1,013,916.71
4,166,543.45
2,117,360.66
2,049,182.79
Total Current Assets 13,201,264.23 13,061,473.15 26,262,737.38 23,649,036.76 2,613,700.62
Capital Assets
Land & Land Rights
690,368.40
3,901,323.35
4,591,691.75
4,590,287.00
1,404.75
Depreciable Capital Assets
89,042,084.34
41,260,565.70
130,302,650.04
129,510,003.63
792,646.41
Accumulated Depreciation
(52,339,258.71)
(15,165,901.36)
(67,505,160.07)
(63,873,667.19)
(3,631,492.88)
Construction - Work in Progress
1,480,283.53
276,130.87
1,756,414.40
792,866.28
963,548.12
Total Net Capital Assets
38,873,477.56
30,272,118.56
69,145,596.12
71,019,489.72
(1,873,893.60)
Other Tangible Property
-
-
-
-
-
Total Net Fixed Assets
38,873,477.56
30,272,118.56
69,145,596.12
71,019,489.72
(1,873,893.60)
Total Assets 52,074,741.79 43,333,591.71 95,408,333.50 94,668,526.48 739,807.02
Current Liabilities
Current Portion of Long-term Debt
Bonds Payable
Bond Premium
Accounts Payable
Accrued Expenses
Accrued Interest
Accrued Payroll
Total Current Liabilities
Long -Term Liabilities
Noncurrent Portion of Long-term Debt
2003 Bonds
2012 Bonds
Bond Premium 2012
Pension Liability- Electric
Pension Liability- Nat Gas
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
OCTOBER 31, 2017
Electric Gas Total Total
Division Division 2017 2016
- 1,220,000.00 1,220,000.00 1,285,000.00
- 185,608.32 185,608.32 185,608.32
2,221,586.03 836,122.22 3,057,708.25 4,317,116.02
Net Change
Total (YTD)
(65,000.00)
(1,259,407.77)
(1,132.86) 306,291.85 305,158.99 338,380.33 (33,221.34)
60,142.86 60,275.44 120,418.30 264,155.92 (143,737.62)
2,280,596.03 2,608,297.83 4,888,893.86 6,390,260.59 (1,501,366.73)
-
15,195,000.00
-
1,500,333.55
4,226,202.00
-
-
1,408,734.00
286,389.60
92,553.90
66,478.09
25,572.23
569,910.00
-
-
189,970.00
5,148,979.69 18,412,163.68
44,645,166.07 22,313,130.20
44,645,166.07 22,313,130.20
-
590,000.00
(590,000.00)
15,195,000.00
16,415,000.00
(1,220,000.00)
1,500,333.55
1,685,941.87
(185,608.32)
4,226,202.00
2,775,239.00
1,450,963.00
1,408,734.00
925,080.00
483,654.00
378,943.50
356,049.33
22,894.17
92,050.32
90,772.86
1,277.46
569,910.00
396,226.00
173,684.00
189,970.00
132,076.00
57,894.00
23,561,143.37
23,366,385.06
194,758.31
66,958,296.27
64,911,880.83
2,046,415.44
66,958,296.27
64,911,880.83
2,046,415.44
Total Liabilities and Net Position 52,074,741.79 43,333,591.71 95,408,333.50 94,668,526.48 739,807.02
Hutchinson Utilities Commission
Cash -Designations Report, Combined
10/31/2017
Savings, Checking, Investments varies varies
Total Operating Funds
Debt Reserve Requirements Bond Covenants - sinking fund
Debt Reserve Requirements Bond Covenants -1 year Max. P & I
Total Reserve Requirement
varies 19,321,608.67 19,840,193.14 (518,584.47)
19,321,608.67 19,840,193.14 (518,584.47)
2,093,046.92 1,930,121.91 162,925.01
2,188,694.02 2,188,694.02 -
4,281,740.94 4,118,815.93 162,925.01
Operating Reserve
Min 60 days of 2017 Operating Bud.
5,973,256.00
5,973,256.00
Rate Stabalization Funds
HUC
Change in
960,597.78
Financial
Charter
1,196,331.00
Balance,
Balance,
Cash/Reserve
500,000.00
Institution
Current Interest Rate
Annual Interest
October 2017
September 2017
Position
3.06
12,080,184.78
12,080,184.78
RONA 0.80%
0.05%
1.31%
2.17%
Savings, Checking, Investments varies varies
Total Operating Funds
Debt Reserve Requirements Bond Covenants - sinking fund
Debt Reserve Requirements Bond Covenants -1 year Max. P & I
Total Reserve Requirement
varies 19,321,608.67 19,840,193.14 (518,584.47)
19,321,608.67 19,840,193.14 (518,584.47)
2,093,046.92 1,930,121.91 162,925.01
2,188,694.02 2,188,694.02 -
4,281,740.94 4,118,815.93 162,925.01
Operating Reserve
Min 60 days of 2017 Operating Bud.
5,973,256.00
5,973,256.00
Rate Stabalization Funds
HUC
960,597.78
960,597.78
PILOT Funds
Charter
1,196,331.00
1,196,331.00
Catastrophic Funds
Risk Mitigation Amount
500,000.00
500,000.00
Capital Reserves
5 Year CIP ( 2017-2021 Fleet & Infrastructure Maintenance)
3,450,000.00
3,450,000.00
Total Earmarked Funds
3.06
12,080,184.78
12,080,184.78
YE
YE
YE
YE
YTD
HUC
2013
2014
2015
2016
2017
Target
Debt to Asset 29.7%
28.8°%
32.0°%
32.2°%
29.8°%
Current Ratio 2.08
2.26
2.52
3.06
4.02
18,112,875
RONA 0.80%
0.05%
1.31%
2.17%
1.99%
Ftt
Change in Cash Balance (From 12/31/14 to 9/30/2017)
Month End
Electric
Elec. Change
Natural Gas
Gas Change
Total
Total Change
10/31/2017
8,023,349
11,298,260
19,321,609
12/31/2016
8,612,801
(589,452)
9,500,074
1,798,186
18,112,875
1,208,734
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
Hutchinson Utilities Commission
Cash -Designations Report, Electric
10/31/2017
Savings, Checking, Investments varies varies
Total HUC Operating Funds
Debt Restricted Requirements Bond Covenants - sinking fund
varies 19,321,608.67 19,840,193.14 (518,584.47)
19,321,608.67 19,840,193.14 (518,584.47)
137,946.88 137,946.88
Operating Reserve
Min 60 days of 2017 Operating Bud.
4,306,719.00
4,306,719.00
Rate Stabalization Funds
$400K -$1.2K
Change in
314,539.41
Financial
Charter
829,200.00
Balance,
Balance,
Cash/Reserve
400,000.00
Institution
Current Interest Rate
Annual Interest
October 2017
September 2017
Position
Current Ratio 2.77
8,600,458.41
8,600,458.41
3.57
4.96
1.81
NN
�I
Savings, Checking, Investments varies varies
Total HUC Operating Funds
Debt Restricted Requirements Bond Covenants - sinking fund
varies 19,321,608.67 19,840,193.14 (518,584.47)
19,321,608.67 19,840,193.14 (518,584.47)
137,946.88 137,946.88
Operating Reserve
Min 60 days of 2017 Operating Bud.
4,306,719.00
4,306,719.00
Rate Stabalization Funds
$400K -$1.2K
314,539.41
314,539.41
PILOT Funds
Charter
829,200.00
829,200.00
Catastrophic Funds
Risk Mitigation Amount
400,000.00
400,000.00
Capital Reserves
5 Year CIP ( 2017-2021 Fleet & Infrastructure Maintenance)
2,750,000.00
2,750,000.00
Total Designated Funds
Current Ratio 2.77
8,600,458.41
8,600,458.41
3.57
4.96
YE
YE
YE
YE
YTD
APPA Ratio
HUC
2013
2014
2015
2016
2017
5K -10K Cust.
Target
Debt to Asset Ratio 8.0%
7.4%
13.2%
16.1%
14.3%
29.5%
VIII
Current Ratio 2.77
2.48
2.95
3.57
4.96
1.81
NN
�I
RONA -2.7%
-3.1%
-1.2%
-0.4%
0.4%
NA
��
Hutchinson Utilities Commission
Cash -Designations Report, Gas
10/31/2017
Savings, Checking, Investments varies varies
Total HUC Operating Funds
Debt Restricted Requirements Bond Covenants - sinking fund
Debt Restricted Requirements Bond Covenants -1 year Max. P & I
Total Restricted Requirements
varies 19,321,608.67 19,840,193.14 (518,584.47
19,321,608.67 19,840,193.14 (518,584.47
1,955,100.04 1,792,175.03 162,925.01
2,188,694.02 2,188,694.02 -
4,143,794.06 3,980,869.05 162,925.01
Operating Reserve
Min 60 days of 2017 Operating Bud.
1,666,537.00
1,666,537.00
Rate Stabalization Funds
$200K -$600K
Change in
646,058.37
Financial
Charter
367,131.00
Balance,
Balance,
Cash/Reserve
100,000.00
Institution
Current Interest Rate
Annual Interest
October 2017
September 2017
Position
Current Ratio 1.31
3,479,726.37
3,479,726.37
2.59
3.20
TBD
N
�l1l
Savings, Checking, Investments varies varies
Total HUC Operating Funds
Debt Restricted Requirements Bond Covenants - sinking fund
Debt Restricted Requirements Bond Covenants -1 year Max. P & I
Total Restricted Requirements
varies 19,321,608.67 19,840,193.14 (518,584.47
19,321,608.67 19,840,193.14 (518,584.47
1,955,100.04 1,792,175.03 162,925.01
2,188,694.02 2,188,694.02 -
4,143,794.06 3,980,869.05 162,925.01
Operating Reserve
Min 60 days of 2017 Operating Bud.
1,666,537.00
1,666,537.00
Rate Stabalization Funds
$200K -$600K
646,058.37
646,058.37
PILOT Funds
Charter
367,131.00
367,131.00
Catastrophic Funds
Risk Mitigation Amount
100,000.00
100,000.00
Capital Reserves
5 Year CIP ( 2017-2021 Fleet & Infrastructure Maintenance)
700,000.00
700,000.00
Total Earmarked Funds
Current Ratio 1.31
3,479,726.37
3,479,726.37
YE
YE
YE
YE
YTD
HUC
2013
2014
2015
2016
2017
APGA Ratio
Target
Debt to Asset 58.6%
55.6%
54.8%
51.5%
48.5%
TBD
VIII
Current Ratio 1.31
2.07
2.17
2.59
3.20
TBD
N
�l1l
RONA 5.8%
4.3%
4.7%
5.6%
4.1%
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ELECTRIC DIVISION
Operating Revenue
October 2017
CLASS
AMOUNT
KWH
/KWH
Street Lights
$0.77
14
$0.05500
Electric Residential Service
$374,995.95
3,471,301
$0.10803
All Electric Residential Service
$14,955.67
136,891
$0.10925
Electric Small General Service
$141,555.25
1,331,147
$0.10634
Electric Large General Service
$618,527.83
6,154,995
$0.10049
Electric Large Industrial Service
$935,369.40
11,249,000
$0.08315
Total
$2,085,404.87
22,343,348
$0.09333
Power Adjustment
$0.00960
Rate Without Power Adjustment
$0.08373
Electric Division Year -to -Date
02017$Amount 02016$Amount M2017KWH/10 02016 KWH/10
27,000,000
26,000,000
25,000,000
24,000,000
23,000,000
22,000,000
21,000,000
20,000,000
19,000,000
18,000,000
17,000,000
16,000,000
15,000,000
14,000,000
13,000,000
12,000,000
11,000,000
10,000,000
9,000,000
8,000,000
7,000,000
6,000,000
5,000,000
4,000,000
3,000,000
2,000,000
1,000,000
0
Street Lights Residential All Elec. Small Gen. Large Gen. Large For Resale Total
Resid. Srv. Srv. Industrial
NOTE: Sales for resale includes capacity sales, market sales and Transalta sales.
NATURAL GAS DIVISION
Operating Revenue
OCTOBER 2017
CLASS
AMOUNT
MCF/$
MCF
Residential
$202,056.52
22,299
$9.06124
Commercial
$158,840.52
19,685
$8.06911
Large Industrial
$296,286.84
69,371
$4.27105
Total
$657,183.88
111,355
$5.90170
Fuel Adjustment -$0.00151
Rate Without Fuel Adjustment $7.41170
Natural Gas Division Year -to -Date
® 2017 $ Amount 0 2016 $ Amount ® 2017 MCF 0 2016 MCF
10,000,000
9,000,000
8,000,000
7,000,000
6,000,000
5,000,000
4,000,000
3,000,000
2,000,000
1,000,000
0
Gas Residential Gas Commercial Large Industrial Total
eReliability utage Pie Chart
Start Date:
01/01/2017
End Date:
10/31/2017
Top-level Cause
Tree
13%
Equipment
139
1�1
Storm
13%
Hutchinson Utilities
Commission
Substation:
Circuit:
Report on Outage:
(0) Count
0 Duration
Page 1 of 2
Failure
yd
1�1
https://reliability.publie power. org/reports/causes-pie-chart/utility/91 ?start-- date=O I %2FO I... 11/22/2017
e eliaility U Outage Pie Chart
Outage Cause
Electrical Failure
Equipment Damage
Tree
Storm
Total
Count
5
r R........ R R RI. . 1 .R ^,'.
-ReliabilityStatistics
Start Date
01/01/2017
End Date
10/31/2017
Remove Major Events?
Top-level Cause
Page I of 2
Hutchinson Utilities
Commission
Minimum event duration (in minutes)
Maximum event duration (in minutes)
Substation
V
Circuit
https:Hreliability.publicpower.org/reports/ieee-statistics/utility/91?start-date=01°/`2F01%... 11/22/2017
NBMM=
CAIDI (minutes)
SAIDI (minutes)
Range Results
Event Count
AMERICAN
Fow(:;,r�ng Strong c"'Ornrylul-lific's
""I
Work
Order Description
11701 Plant 1 Door & Window Replacement
11702 Unit #8 Field Breaker/Voltage Control
11703 Unit #8 Boiler Non -Return Valve
11704 Plant 1 Alarm Panel Upgrade
11705 Unit #1 Control System Batteries
11706 Plant 1 Electrical Panel Upgrades
11707 Unit #1 Gas Valve Upgrade
11708 Units 6 and 7
Electric Production
$ 163,500.00 $ 12,000.00 $ 175,500.00 $ 645,866.58 $ 470,366.58
Percentage
Completed
Cancel
50%
100%
0%
100%
0%
100%
25%
Total
Total
Materials
Labor
Budgeted
Actual
Difference
$ 150,000.00
$ 20,000.00
$
170,000.00
$ 7,943.87
$
(162,056.13)
95,000.00
5,000.00
$
100,000.00
113,858.76
$
13,858.76
40,000.00
1,000.00
$
41,000.00
20,224.37
$
(20,775.63)
10,000.00
6,000.00
$
16,000.00
-
$
(16,000.00)
8,500.00
-
$
8,500.00
1,816.97
$
(6,683.03)
10,000.00
-
$
10,000.00
172.20
$
(9,827.80)
-
-
$
-
57,959.49
$
57,959.49
-
-
$
-
451,834.79
$
451,834.79
$ 163,500.00 $ 12,000.00 $ 175,500.00 $ 645,866.58 $ 470,366.58
Percentage
Completed
Cancel
50%
100%
0%
100%
0%
100%
25%
Electric Distribution
Work
Total
Total
Percentage
Order
Description
Materials
Labor
Budgeted
Actual
Difference
_Completed
21701
Pole Repair or Replacement
15,000.00
-
15,000.00
-
$
(15,000.00)
0%
21702
Hutch Substation Roof Replacement
10,000.00
-
10,000.00
-
$
(10,000.00)
0%
21703
Station Equipment
10,000.00
-
10,000.00
-
$
(10,000.00)
0%
21704
Poless, Towers, Fixtures N Hwy 15 Fdr 12A
10,000.00
5,000.00
15,000.00
-
$
(15,000.00)
0%
21705
Right of Way Clearing
2,500.00
2,500.00
182.00
$
(2,318.00)
0%
21706
Duct for Reconductor
20,000.00
65,000.00
85,000.00
105,299.55
$
20,299.55
95%
21707
Reconductor Feeder 17
45,000.00
45,000.00
90,000.00
207,306.77
$
117,306.77
95%
21708
Reconductor Feeder 16
20,000.00
25,000.00
45,000.00
445.89
$
(44,554.11)
0%
21709
Hutchinson High School
35,000.00
25,000.00
60,000.00
33,755.03
$
(26,244.97)
75%
21710
New Developments
50,000.00
-
50,000.00
99,674.69
$
49,674.69
80%
21711
Hutchinson High School
25,000.00
1,000.00
26,000.00
21,123.23
$
(4,876.77)
100%
21712
Transformer Replacements
40,000.00
10,000.00
50,000.00
857.74
$
(49,142.26)
0%
21713
New Developments
50,000.00
-
50,000.00
17,705.97
$
(32,294.03)
80%
21714
Meters
30,000.00
-
30,000.00
6,685.08
$
(23,314.92)
20%
$ 360,000.00
$ 178,500.00
$ 538,500.00
$ 493,035.95
$
(45,464.05)
Work Order
Description
51701
Vactron
51702
F550 Dump Truck
51703
F550 Super Duty Bucket Truck
51704
Tractor Backhow
51705
Lift
Administrative
Total
Total
Percentage
Budgeted
Actual
Difference
Completed
60,000.00
37,864.00
22,136.00
100%
30,000.00
-
30,000.00
0%
130,000.00
131,206.11
(1,206.11)
0%
60,000.00
61,827.19
(1,827.19)
100%
17,000.00
16,733.20
$ (266.80)
100%
$ 297,000.00 $ 247,630.50 $ (49,369.50)
Natural Gas
,,~~
Total
Total
percentage
Order
Description
Materials
Labor
Budgeted
Actual
Difference gqM21eted
61701
Transmission Lateral toHCP ROW Easements
$ 500,000.00
g s'000.00
$ soa'uoo.00
g 1'404.75
$ (501,595.25) Cancel
61702
Transmission Lateral toHCP Materials and Permits
$ 500,000u0
g s'000.00
$ sos'000.00
g -
$ (503,000.00) Cancel
61703
Interconnect Station *anska
200,000.00
m'000uo
$ 210'000u0
226s0
$ (209,773.50) Cancel
61704
MiscDevelopments and Improvements
30,000.00
zs'000.00
$ 45'000.00
89'565.94
$ 44,565.94 om
azros
specmcsravityMete,-*utcmnmn
40.ououo
1'000-00
$ 41,000.00
6'75849
$ (34'241s1) mom
azma
sc4oxsquipment *anska
15'000u0
s'000.00
$ 20,000.00
163.39
$ (1e'836a1) Cancel
azrou
Regulator Station Improvements
15'000.00
s'00000
$ 18'000o0
-
$ (zm'000.00) om
aooa
Service Lines
ss'000.00
20,000u0
g 75'000.00
/1'8e8s7
$ (3'101.43) mm
61710
Meters, Regulators, AMI Modules
ro'ouo.00
s'soo.00
$ 73.500.00
/5'542.3/
$ 2'042.37 sm
61711
Industrial Metering and Regulation
20'000.00
3,500.00
$ 23'500.00
e'auaua
$ <13'811.94> om
61/12
Gas Detection Equipment
soouoo
---���
-_
$__�000.00
-_
$__(5�00.00) um
$ 1,450,000.00
$ 67,000.00
$ 1,517,000.00
$ 255,248.07$
(1,261,751y3)
OS
HUTCHINSON UTILITIES COMMISSION 9T,
Board Action Form
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Agenda Item: Review Policies
Presenter: Jeremy Carter 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. Appendix A - Acknowledgement
ii. Appendix B — New Employee Acknowledgement
iii. Appendix C - Temporary Employee Acknowledgement
iv.Appendix D —Acknowledgement
v. Landlord Acknowledgement
vi. Inserts with Utility Bills
vii. Financial Reserve Policy
BOARD ACTION REQUESTED:
None
Fiscal Impact:
Included in current budget: Budget Change:
PROJECT SECTION:
Total Project Cost: RemainingCost:
EXEMPT
APPENDICES
APPENDIX A - ACKNOWLEDGEMENT
I, acknowledge that I have received a copy of the Hutchinson Utilities
Employee Handbook and that I am responsible for being familiar with its contents. I understand the
Hutchinson Utilities Employee Handbook does not create a contract between Hutchinson Utilities and me.
I also understand that Hutchinson Utilities may revise the contents of the Employee Handbook at its
discretion.
Date:
NON-EXEMPT
I
Employee's Signature
APPENDIX A - ACKNOWLEDGEMENT
acknowledge that I have received a copy of the Hutchinson Utilities
Employee Handbook and that I am responsible for being familiar with its contents. I understand the
Hutchinson Utilities Employee Handbook does not create a contract between Hutchinson Utilities and me.
I also understand that Hutchinson Utilities may revise the contents of the Employee Handbook at its
discretion.
Date:
Employee's Signature
EXEMPT
APPENDIX B — NEW EMPLOYEE ACKNOWLEDGEMENT
I, , have been hired by the Hutchinson Utilities Commission ("the
Commission") as . I acknowledge that I will serve a nine (9) month
probationary period, ending the __ day of 20_, unless the General Manager
extends my probation a maximum of three (3) additional months. I understand that until my probationary
period is completed, the Commission may terminate me at any time and without cause.
Date:
NON-EXEMPT
Employee's Signature
APPENDIX B — NEW EMPLOYEE ACKNOWLEDGEMENT
I, , have been hired by the Hutchinson Utilities Commission ("the
Commission") as . I acknowledge that I will serve a six (6) month
probationary period, ending the __ day of 20_, unless the General Manager
extends my probation a maximum of three (3) additional months. I understand that until my probationary
period is completed, the Commission may terminate me at any time and without cause.
Date:
Employee's Signature
EXEMPT
APPENDIX C - TEMPORARY EMPLOYEE ACKNOWLEDGEMENT
I, _ , have been hired by the Hutchinson Utilities Commission ("the
Commission") as , which is a temporary position. I acknowledge that this
position will not exceed six (6) months and the Commission may terminate it without cause at any time. I
also understand I accrue no rights to reappointment to this position if it becomes open again in the future.
I understand as a temporary employee, I am not entitled to any benefits, and that I may be terminated
from the position at any time and without cause.
Date:
NON-EXEMPT
Employee's Signature
APPENDIX C - TEMPORARY EMPLOYEE ACKNOWLEDGEMENT
I, , have been hired by the Hutchinson Utilities Commission ("the
Commission") as , which is a temporary position. I acknowledge that this
position will not exceed six (6) months and the Commission may terminate it without cause at any time. I
also understand I accrue no rights to reappointment to this position if it becomes open again in the future.
I understand as a temporary employee, I am not entitled to any benefits, and that I may be terminated
from the position at any time and without cause.
Date:
Employee's Signature
EXEMPT
I
APPENDIX D - ACKNOWLEDGEMENT
acknowledge that I have received a copy of the APPA -Utilities Safety
Handbook and that I am responsible for being familiar with its contents. I understand I must follow all
safety rules and regulations in the APPA Safety Handbook and any other safety rules adopted by
Hutchinson Utilities.
Date:
NON-EXEMPT
Employee's Signature
APPENDIX D - ACKNOWLEDGEMENT
I, acknowledge that I have received a copy of the APPA -Utilities Safety
Handbook and that I am responsible for being familiar with its contents. I understand I must follow all
safety rules and regulations in the APPA Safety Handbook and any other safety rules adopted by
Hutchinson Utilities.
Date:
Employee's Signature
Landlord Acknowledgement
A signed Landlord Acknowledgement provides the following:
• Confirmation and documentation of the landlord/owner.
• Request of HUC to provide utility service to tenants.
• The understanding that the tenant will be responsible for all utility costs between
the date service is required by the tenant and the date the tenant requests read-
out of services.
• The landlord/owner agrees to be responsible for and to pay all utility charges from
the read-out date given by the tenant until services are established with a new
tenant.
• The understanding that failure to pay these charges could result in disconnection
of electric service. HUC is not responsible for any damages alleged to be caused
by service disconnection. Disconnection/reconnection fees apply.
• The landlord/owner has the option to contact HUC to confirm that the utility service
has been placed in the tenant's name.
• The landlord /owner can request the disconnection of services as long as the
account is in the landlord's/owner's name. Disconnection/reconnection fees apply.
Inserts with Utility Bills
Generally, only material which applies directly to HUC business may be inserted into monthly
utility bill mailings. HUC may approve the inclusion of other items, as appropriate.
HUTCHINSON UTILITIES FINANCIAL RESERVE POLICY
A. PURPOSE:
In order to maintain stable rates and provide reliable service, Hutchinson Utilities Commission
(HUC) must have various tools in place to deal with changes in costs or operational
performance. Maintaining appropriate financial reserves is one such tool that ensures
sufficient funding is available for current operating, capital and debt service needs. Financial
reserves absorb short-term financial variability resulting from unexpected operational
changes or can reduce the need for large amounts of debt. This policy establishes a Capital
Reserve (CR), which is used to cover acquisition of capital assets, including replacement of
existing assets, and an Operating Reserve (OR), which addresses short-term financial
volatility. HUC will establish a Capital Reserve and Operating Reserve for each of the two
utilities — Electric and Gas.
B. DEFINITIONS:
Hutchinson Utilities Commission reserves can be classified into three broad categories that
include Restricted Cash Reserves, Capital Reserve Funds, and Operating Reserve Funds. A
"fund" is a segregation within the Utility's accounting system to keep sources and uses for a
particular purpose easily identifiable and reportable.
C. GENERAL PROVISIONS
In the context of funding future capital equipment or facilities or replacing existing assets
with substantial value HUC will analyze the most cost effective and efficient method to
finance a project, be it through debt financing, pay -as -you go financing, use of reserves, use
of contractual agreements, or through some combination of those various sources or others
that may present themselves.
At a minimum, reserve balances will be reviewed on an annual basis at, or near, the end of
the fiscal year during preparation of the Capital & Operating Spending Plans to ensure
adequate compliance with policy and intended funding targets. The minimum funding
requirements established for each fund represents the baseline financial condition that is
acceptable to the Commission from a risk and long-range financial planning perspective.
Maintaining reserves at appropriate levels is a prudent, ongoing business process that
consists of an assessment and application of various revenue generating alternatives. These
alternatives (either alone or in combination with each other) include, but are not limited to:
fees & charges, capital financing, investment of funds, contractual commitments, and levels
of capital expenses.
L RESTRICTED RESERVES (RR) - Restrictions on these monies are imposed by an
outside source such as creditors, grantors, contributors, laws or regulations governing
use. An example of restricted funds is bond reserve covenants required as a part of debt
issuance. The funds are legally protected by bond covenants and can only be used in
the event of default by HUC or to pay down principal at maturity.
A. Funding Amount — The bond reserve requirements are established at the time
of bond issuance.
B. The sources of funds for the (RR) come from the undesignated fund balance of
each utility which can change annually based on yearly operating performance
and accumulated net revenues and, when appropriate, available short-term
liquidity arrangements.
IL CAPITAL RESERVES (CR) - This reserve is established by action of the board to
fund capital projects including electric and gas distribution & transmission system
infrastructure, production facilities, and fleet that are a part of the 5 -year capital
improvement plan so HUC can avoid issuing bonds to pay for maintaining normal
operations. This reserve is not intended to fund large major capital purchases.
(i.e...Fleet, infrastructure replacement or acquisitions)
A. Funding Amount — Minimum funding shall be targeted at the estimated current
replacement costs of assets expected to be replaced within the next five years.
B. Funding Sources — The sources of funds for the (CR) come from the
undesignated fund balance of each utility which can change annually based on
yearly operating performance and accumulated net revenues and, when
appropriate, available short-term liquidity arrangements.
III. OPERATING RESERVES (OR) — This reserve is established by action of the board
to address short-term financial risk or variability resulting from unexpected operating
results and to address those financial risks that have a more immediate potential impact
on the existing organization cost structure. (i.e... Rate Stabilization Reserve Funds,
Catastrophic Reserve Funds, PILOT Reserve Funds, Operating Reserves)
A. Risk Exposures — Potential sources of cash flow variability addressed by the
(OR) include the following risk exposures:
1. Reductions in overall customer demand,
2. Changes in total system load resulting from the actions of large
customers,
3. Failure to achieve the budgeted level of net income,
4. Changes in the costs of purchased power,
5. Catastrophic disasters or community events
6. General operation exposures, such as timing mismatch between
revenue receipts and expense payment, unforeseen maintenance
costs, regulatory compliance costs, and other unexpected increases
in the operating budget
B. Funding Amount— Target (OR) level has been set at a minimum of 60 days and
a maximum of 90 days of total budgeted operating expenses for both the
Electric Division and Gas Division. Since the (OR) changes annually for each
division based on the following years budget, the (OR) will be adjusted
annually. The (OR) target is in addition to the other operating reserve funds
listed above.
C. Funding Sources — The sources of funds for the (OR) come from the
undesignated fund balance of each utility which can change annually based on
yearly operating performance and accumulated net revenues and, when
appropriate, available short-term liquidity arrangements.
IV. FINANCIAL RESERVES HIERARCHY OF FUNDING — The following lists the
priorities applied to HUC's reserves.
A. Maintaining Operating Reserves (OR) within a 60 day to 90 day operating
range.
B. Once the Target (OR) level is achieved, excess cash may be applied to the (CR)
or other areas at the discretion of the Hutchinson Utilities Commission.
V. FINANCIAL RESERVES REPLENISHMENT— The above section describes the
hierarchy of funding the reserves. The following describes what actions may be taken
to generate cash and replenish the reserves under different scenarios of each of the two
utilities.
A. If the (OR) and (CR) are at the Target Level: Take no action
B. If either the (OR) or (CR) is below the Target Level or if both the (OR) and
(CR) are below the Target Level: Take no action during the current year,
reevaluate the following year and reduce expenses and/or increase revenues, if
necessary, to reach the Target Level within the next three years.
VI. FINANCIAL RESERVES FUNDING LEVEL AND FUND BALANCE
REVIEWS — The Target levels and fund balance are to be reviewed as follows:
A. Target Level Review: Although the actual monetary values are reviewed
annually and adjusted to reflect target goals when approving budgets, the Target
(OR) and (CR) funding levels are to be evaluated every year. For example, the
Commission could revise (reduce or increase) the (OR) or (CR) reserves based
on future external factors and forward looking cost drivers.
B. Financial Reserves Fund Balance Review: The (OR) and (CR) fund balances
are to be monitored monthly by the Finance Department and reviewed annually
during the budget review process by the Commission or if an event were
suddenly to reduce the fund balances.
HUTCHINSON UTILITIES COMMISSION ���*N�'
Board Action Form
'or, Hits
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Agenda Item: Approve Policy Changes
Presenter: Jeremy Carter Agenda Item Type:
Time Requested (Minutes): 5 App Changes to Policies
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. After Hours Reconnection Policy
BOARD ACTION REQUESTED:
Approve Policy Changes
Fiscal Impact:
Included in current budget: Budget Change:
PROJECT SECTION:
Total Project Cost: Remaining Cost:
After Hours Reconnection Policy
No after hours reconnections will be done from 9:00 p.m. to 7:30 a.m. Monday through Friday nor
from 9:00 p.m. to 8:00 a.m. on weekends and holidays.
After hours reconnection fees:
A $150 Reconnection Fee will be charged for any reconnection that is done:
• From 4:00 p.m. to 9:00 p.m. on Monday through Friday
• From 8:00 a.m. to 9:00 p.m. on Saturdays
A $200 Reconnection Fee will be charged for any reconnection that is done:
• From 8:00 a.m. to 9:00 p.m. on Sundays or Holidays
Payments must be made prior to reconnecting utilities. Office hours are 7:30 a.m. to 4:00 p.m.
Monday through Friday, excluding holidays. After hour payments can only be made with credit
card, debit card or electronic check.
Holidays include the following: New Year's Day, Martin Luther King Day, President's Day,
Memorial Day, Independence Day, Labor Day, Veterans Day, Thanksgiving Day, Christmas Eve
Day, and Christmas Day.
HUTCHINSON UTILITIES COMMISSION
Board Action Form
&F,WK,
Agenda Item: Approve Charge Offs
Presenter: Jared Martig
Agenda Item Type:
Time Requested (Minutes): 2
New Business
Attachments: Yes
BACKGROUND/EXPLANATION OF AGENDA ITEM:
We are requesting that you approve the charge-offs in the amount of $31,967.78 as
shown on the attached spreadsheet. Past amounts written off are listed below.
2016: $11,350.31
2015: $ 7,537.92
2014: $41,279.16
2013: $ 4,316.12
2012: $ 4,067.15
2011: $ 9,792.12
BOARD ACTION REQUESTED:
Approve Charge Offs
Fiscal Impact:
Included in current budget: Budget Change:
PROJECT SECTION:
Total Project Cost: Remaining Cost:
Bankruptcy
ACCOUNT#
AMT. OWING
ELECTRIC
NAT. GAS
REASON FOR
LAST
CHARGE OFF
ACTIVITY DATE
437000
$142.98
$142.98
$0.00
Bankruptcy
3/25/2014
20000
$751.49
$209.36
$542.13
Bankruptcy
11/21/2016
20002
$770.57
$17.83
$752.74
Bankruptcy
11/21/2016
20003
$1,365.08
$18.57
$1,346.51
Bankruptcy
11/21/2016
20004
$247.99
$247.99
$0.00
Bankruptcy
11/21/2016
20005
$109.38
$109.38
$0.00
Bankruptcy
11/21/2016
20006
$133.92
$133.92
$0.00
Bankruptcy
11/21/2016
20007
$91.46
$91.46
$0.00
Bankruptcy
11/21/2016
20008
$71.27
$71.27
$0.00
Bankruptcy
11/21/2016
20009
$280.73
$280.73
$0.00
Bankruptcy
11/21/2016
20011
$48.45
$48.45
$0.00
Bankruptcy
11/21/2016
20012
$443.26
$443.26
$0.00
Bankruptcy
11/21/2016
20013
$50.01
$50.01
$0.00
Bankruptcy
11/21/2016
31110
$89.51
$54.35
$35.16
Bankruptcy
4/11/2017
BANKRUPTCY TOTAL
$4,596.10
$1,919.56
$2,676.54
$4,596.10
Deceased
ACCOUNT#
AMT. OWING
ELECTRIC
NAT. GAS
REASON FOR
LAST
435112
$11.90
$11.90
$0.00
Deceased
7/24/2017
300075
$40.41
$25.03
$15.38
Deceased
3/9/2017
380210
$356.87
$158.40
$198.47
Deceased
8/8/2016
280590
$332.23
$281.12
$51.11
Deceased
5/22/2017
214105
$74.17
$74.17
Deceased
9/22/2017
DECEASED TOTAL $815.58 $550.62 $264.96 $815.58
ACCOUNT#
AMT. OWING
ELECTRIC
NAT. GAS REASON FOR
LAST
CHARGE OFF
ACTIVITY DATE
00121640
$117.52
$0.00
$117.52
7/3/2012
00370805
$6.58
$6.58
$0.00
2/3/2016
00190305
$24.73
$24.73
$0.00
1/9/2012
00280745
$67.72
$45.30
$22.42
5/20/2015
00453009
$24.67
$24.67
$0.00
5/21/2014
00030695
$15.76
$15.76
$0.00
2/19/2014
00212131
$12.57
$12.57
$0.00
11/12/2015
00121036
$91.40
$66.01
$25.39
7/20/2015
00420084
$19.27
$19.27
$0.00
11/27/2012
00190235
$214.08
$145.69
$68.39
10/13/2014
00420561
$84.98
$84.98
$0.00
9/23/2014
00010063
$372.32
$144.74
$227.58
4/20/2015
00121422
$20.90
$20.90
$0.00
2/14/2013
00420334
$276.54
$276.54
$0.00
4/5/2013
00030755
$10.73
$10.73
$0.00
11/7/2011
00420386
$20.88
$20.88
$0.00
9/21/2012
00101125
$165.26
$165.26
$0.00
11/9/2015
00470338
$23.41
$0.00
$23.41
2/21/2012
00050185
$2,966.51
$397.48
$2,569.03
12/14/2011
00050180
$194.81
$59.09
$135.72
1/9/2012
00140410
$20.10
$20.10
$0.00
7/25/2013
00060350
$19.85
$0.00
$19.85
7/9/2014
00040305
$108.58
$0.00
$108.58
6/8/2012
00420056
$24.39
$24.39
$0.00
5/20/2016
00370514
$38.97
$0.00
$38.97
10/15/2012
00420430
$81.06
$81.06
$0.00
9/13/2012
00260250
$32.27
$32.27
$0.00
7/20/2015
00191001
$24.85
$24.85
$0.00
12/21/2015
00060615
$82.65
$82.65
$0.00
3/31/2016
00111150
$20.08
$20.08
$0.00
2/8/2012
00470127
$144.61
$144.61
$0.00
1/8/2013
00420004
$59.39
$59.39
$0.00
6/12/2015
00390112
$14.27
$14.27
$0.00
7/23/2012
00420334
$72.93
$72.93
$0.00
11/30/2012
00260248
$108.34
$108.34
$0.00
6/2/2015
00030735
$23.55
$23.55
$0.00
5/18/2016
00470124
$22.62
$22.62
$0.00
3/21/2014
00260601
$12.51
$12.51
$0.00
1/30/2012
00420325
$154.76
$154.76
$0.00
10/24/2011
00260285
$43.62
$43.62
$0.00
6/23/2014
00060640
$95.24
$95.24
$0.00
10/10/2012
00350615
$23.08
$23.08
$0.00
5/4/2015
00030350
$10.52
$10.52
$0.00
1/22/2014
00420376
$21.02
$21.02
$0.00
5/16/2013
110966
$68.88
$54.10
$14.78
8/8/2016
60635
$10.55
$10.55
$0.00
4/17/2017
190650
$1.87
$1.87
$0.00
4/17/2017
210700
$5.40
$5.40
$0.00
5/15/2017
260283
$20.84
$20.84
$0.00
4/17/2017
350451
$13.31
$13.31
$0.00
4/17/2017
260283
$55.87
$55.87
$0.00
1/4/2017
320201
707.63
$177.41
$530.22
9/7/2010
20380
566.19
$566.19
$0.00
8/16/2010
420006
50.02
$50.02
$0.00
9/9/2010
390030
422.45
$124.19
$298.26
11/22/2010
420376
121.37
$121.37
$0.00
12/2/2010
280560
339.63
$0.00
$339.63
11/17/2010
30745
128.38
$128.38
$0.00
10/14/2010
350446
241.79
$0.00
$241.79
12/10/2010
30950
39.82
$39.82
$0.00
2/11/2011
310195
393.36
$22.57
$370.79
11/15/2010
470023
145.20
$145.20
$0.00
2/1/2011
121413
464.30
$464.30
$0.00
1/21/2011
260395
323.51
$0.00
$323.51
4/21/2011
60410
1,039.16
$1,039.16
$0.00
1/18/2011
121230
1,527.20
$0.00
$1,527.20
4/19/2011
420162
507.41
$507.41
$0.00
10/15/2010
370937
118.73
$118.73
$0.00
3/29/2011
90240
914.53
$165.04
$749.49
3/18/2011
420342
338.97
$338.97
$0.00
2/14/2011
120390
522.36
$112.84
$409.52
2/24/2011
80455
70.72
$70.72
$0.00
3/28/2011
110635
100.34
$100.34
$0.00
4/18/2011
40560
698.50
$15.16
$683.34
2/22/2011
110645
445.14
$28.08
$417.06
1/23/2009
60095
123.14
$0.00
$123.14
9/2/2008
60615
96.38
$96.38
$0.00
7/23/2008
60625
401.30
$401.30
$0.00
6/20/2008
120620
179.58
$9.64
$169.94
9/8/2008
340034
431.60
$14.25
$417.35
3/16/2009
340322
946.01
$543.52
$402.49
1/12/2009
70920
514.73
$0.00
$514.73
10/27/2008
60576
50.00
$0.00
$50.00
12/16/2008
230015
117.35
$0.00
$117.35
12/18/2008
160620
437.82
$199.65
$238.17
3/11/2009
121645
578.53
$237.19
$341.34
10/28/2008
190530
83.84
$83.84
$0.00
1/26/2009
210709
52.38
$52.38
$0.00
1/12/2009
140609
174.65
$174.65
$0.00
11/25/2008
340005
439.18
$130.94
$308.24
2/17/2009
370610
214.43
$23.75
$190.68
12/15/2008
110605
1,793.34
$515.73
$1,277.61
2/22/2011
420458
74.99
$74.99
$0.00
3/8/2011
220275
1,185.14
$310.28
$874.86
4/5/2011
30952
60.13
$60.13
$0.00
5/12/2011
162027
163.93
$163.93
$0.00
3/10/2011
190645
142.35
$142.35
$0.00
7/15/2009
160260
411.51
$175.39
$236.12
7/2/2010
420328
124.86
$124.86
$0.00
6/6/2011
60250
478.17
$92.24
$385.93
6/14/2011
220031
40.19
$0.00
$40.19
7/20/2011
00280355
124.34
$92.16
$32.18
6/28/2011
00260601
75.12
$44.88
$30.24
8/8/2011
00060640
153.91
$153.91
$0.00
9/19/2011
00121418
181.70
$181.70
$0.00
8/9/2011
30335
312.17
$250.30
$61.87
9/2/2011
Uncollectable Total
$26,556.10
$11,481.22
$15,074.88
$26,556.10
Grand Total
$31,967.78
$13,951.40
$18,016.38
$31,967.78