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06-25-2025 HUCCPHUTCHINSON UTILITIES COMMISSION AGENDA REGULAR MEETING June 25, 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 6 of Exempt Handbook ii. Section 6 of Non -Exempt Handbook b. Approve Changes i. Accidents and Injuries (Exempt and Non -Exempt) ii. Unsafe Conditions or Practices (Exempt and Non -Exempt) iii. Protected Safety Footwear (Exempt and Non -Exempt) 7. UNFINISHED BUSINESS 8. NEW BUSINESS a. Approve Req# 010270 — Close Interval Survey b. Approve Req# 010278 — Generator #1 Transformer Radiator Repair 9. ADJOURN MINUTES Regular Meeting — Hutchinson Utilities Commission Wednesday, May 28, 2025 Call to order — 3:00 p.m. President Matt Cheney called the meeting to order. Members present: President Matt Cheney; Secretary Don Martinez; Vice President Troy Pullis; Commissioner Kathy Silvernale; Commissioner Tom Lambert; GM Jeremy Carter; Attorney Marc Sebora: 1. Conflict of Interest 2. Approve Consent Agenda a. Approve Minutes b. Ratify Payment of Bills Motion by Commissioner Martinez second by Commissioner Pullis to Approve the Consent Agenda. Motion carried unanimously. 3. Approve Financial Statements Mr. Martig presented the Financial Statements. Electric Division Net Income increased by $366k over last year. Main reason was an increase in market sales of $470k due to high prices on April 1 and 2, which also increased generator fuels. Sales for Resales also increased due to the increase in market sales. Mr. Martig noted usage going forward for the year will show an increase in Large General and a decrease in Industrial due to a customer reclassification. Natural Gas Division is very consistent from last year. GM Carter reviewed the Rate Stabilization fund and Power Cost Adjustment. Motion by Commissioner Silvernale, second by Commissioner Lambert to Approve the Financial Statements. Motion carried unanimously. 4. Open Forum 5. Communication a. City Administrator —Matthew Jaunich — i. Construction season - Hassan and Dale street. ii. Exploring options to extend Utilities East of town '7=big015607 i. Dan Lang, Engineering Services Manager — 1. Willmar Line Transmission Project with GRE update. Open Houses are scheduled for June 18tn and 19tn ii. Dave Hunstad, Electric Transmission/Distribution Manager — 1. Construction season starting iii. Mike Gabrielson, Production Manager — 1. Tuck pointing has started 1 2. Stack Testing on Unit 5 is scheduled for June 12tn iv. Byron Bettenhausen, Natural Gas Manager — Nothing to report v. Jared Martig, Financial Manager - Nothing to report c. Human Resources — Angie Radke - i. Working with Byron on Natural Gas tasks d. Legal — Marc Sebora — i. Nothing to report e. General Manager — Jeremy Carter i. Working on possible Tolling Agreement ii. Working on energy contract with prospective customer iii. Draft agreement has been sent off to New Ulm iv. Working on Capacity Agreement that is on the Agenda for discussion 6. Policies a. Review Policies i. Section 5 of Exempt Handbook ii. Section 5 of Non -Exempt Handbook No changes recommended at this time b. Approve Changes i. Vacation (Exempt) ii. Holidays (Exempt and Non -Exempt) iii. Pregnancy and Parenting Leave (Exempt and Non -Exempt) iv. Reasonable Accommodations to an Employee for Health Conditions Relating to Pregnancy (Exempt and Non -Exempt) v. Sick Leave (Exempt and Non -Exempt) vi. Training and Education Assistance (Exempt and Non -Exempt) vii. Small Hand Tools (Non -Exempt) Ms. Radke spoke of the policy changes. All policies listed above with the exception of Pregnancy and Parenting Leave were updated to remove the word Director from the policies, policies are still applicable. Pregnancy and Parenting Leave policy was updated to mirror the League of Minnesota Cities policy. Motion by Commissioner Pullis, second by Commissioner Silvernale to Approve Policy Changes. Motion carried unanimously. 7. Unfinished Business 8. New Business a. Approve Exception Agreement between McLeod Cooperative Power and Hutchinson Utilities Commission 2 Mr. Hunstad presented Approval of Exception Agreement between McLeod Cooperative Power and Hutchinson Utilities Commission. In 2024, IND School District 0423 property located at 1440 South Grade Road SW was annexed into the City and became part of HUC's service territory. The property consists of a small shed and green house with a security light. Due to the small load and distance from HUC's electric infrastructure, Staff is recommending to allow MCP to continue to serve the property as it is today under an exception agreement. Mr. Hunstad noted that L&P Supply of Hutchinson, is currently served by MCP under an exception agreement made in 2018. Motion by Commissioner Martinez, second by Commissioner Lambert to Approve Exception Agreement between McLeod Cooperative Power and Hutchinson Utilities Commission. Motion carried unanimously. b. Approve Change Order #1 to Border States Electric for the Addition of Circuit Breaker Metering CT's Mr. Lang presented Approval of Change Order #1 to Border States Electric for the Addition of Circuit Breaker Metering CT's. Since the time the circuit breakers were ordered there has been some design changes. Motion by Commissioner Silvernale, second by Commissioner Pullis to Approve Change Order #1 to Border States Electric for the Addition of Circuit Breaker Metering CT's. Motion carried unanimously. c. Approve Capacity Confirmation Agreement GM Carter presented Approval of Capacity Confirmation Agreement. Staff is looking into extending excess capacity into an agreement. Right now, HUC has 41 MW excess capacity from the generating units in town. Currently there are 2 contracts in place that consist of the 41 MW, which will expire in May of 2030. Conversations have been held in the past if HUC should extend the contracts. HUC and NextEra Energy Marketing LLC (NEM) have been working on an agreement that would be for a 5-year term (PY2030/2031-2034/2035) with a price at minimum of $6.90/kW-Month. In the course of NEM consummating a final agreement with their counter -party, and if the price is higher than $6.90kW-Month, a revised agreement or an addendum to this agreement will come back before the board for approval. Discussion was held on the market pricing and timing of the agreement along with the clause if HUC cannot deliver. Motion by Commissioner Pullis, second by Commissioner Lambert to Approve Capacity Confirmation Agreement. Motion carried unanimously. 3 d. Set Joint Special Meeting for June 4, 7am-9am with City Council and EDA at Hutchinson City Center Motion by Commissioner Martinez, second by Commissioner Silvernale to Set Joint Special Meeting for June 4, 7am-9am with City Council and EDA at Hutchinson City Center. Motion carried unanimously. 9. Adjourn There being no further business, a motion by Commissioner Pullis, second by Commissioner Martinez to adjourn the meeting at 3:31 p.m. Motion carried unanimously. ATTEST: Matt Cheney, President 12 Don Martinez, Secretary Special Meeting MINUTES Special Meeting — Hutchinson Utilities Commission Wednesday, May 28, 2025 Call to order — 2:00 p.m. President Matt Cheney called the meeting to order. Members present: President Matt Cheney; Secretary Don Martinez; Vice President Troy Pullis; Commissioner Kathy Silvernale; Commissioner Tom Lambert; GM Jeremy Carter; Attorney Marc Sebora: Others present: Jared Martig, Dave Hunstad, Dan Lang, Mike Gabrielson, Byron Bettenhausen, and Angie Radke GM Carter introduced Byron Bettenhausen — Natural Gas Manager. Purpose of meeting is to have Cash Flow and Financing Discussion. GM Carter thanked the Commissioners for coming in and provided an overview of the meeting. GM Carter started with giving a Willmar Line update and informing the Commission about the open houses coming soon. GM Carter discussed the Hutchinson Substation Upgrade along with the different Cash Flow options and any overlap that may happen with the Willmar Line project. GM Carter also noted how some of the distribution work at Plant 1 will not be reimbursable as part of the Willmar Line Project but the transmission costs can be recoverable through Schedule O. Initial project investment for the Hutch Substation improvements is $14.6M which did factor in some contingency for a couple more change orders. GM Carter reviewed the Combined Division Reserves Table for years 2022-2030. The table shows the beginning year excess/deficit combined cash balance for each year and does include proposed rate increases but does not include using cash from the electric or natural gas division to fund the remaining Hutch Sub Station project ($12.6M). The table represents in the years there is excess cash to cover all the restricted and minimum designated cash balances approved by the commission or imposed by bond covenants. Table #2 shows Revised Cash Balance with the 2 projects of Hutch Substation Transmission Project and Unit #1 purchases. GM Carter noted years 2025 and 2026 is an interim period where organization cash balance is below forecasted reserves. Table 2 does include rate increases and paying all unit #1 costs and substation project costs with cash on hand and no infusion of cash financing. GM Carter reviewed the Electric Reserves tables for years 2022-2030. The excess/deficit cash balance for each year does include proposed rate increases but does not include using any additional cash from the electric division to fund the remaining Hutch Sub Station project costs of $12.6M. Table 1 represents moving forward there is not enough cash to cover all the restricted and minimum designated cash balances approved by the Commission or imposed by bond covenants. Table 2 shows the projected YE cash balance for each year which does not include the remaining Hutch Sub project costs $12.6M being paid for out of the electric division. Table 3 shows the revision YE cash balance in the electric division if cash is used from the division to pay for the remaining Hutch Sub Project costs $12.6M. $6.3M has already been funded out of the electric 1 division. These tables are to show the Commissioners how the Electric Division cannot fund this project alone. GM Carter reviewed the Natural Gas Division Reserves tables for years 2022-2030. The excess/deficit cash balance for each year includes proposed rate adjustments but does not include using cash from the gas division to fund the Hutch Sub Station project or Unit #1 purchase. Table 1 represents in the years there is excess cash to cover all the restricted and minimum designated cash balances approved by the commission or imposed by bond covenants. Table 2 shows the projected YE cash balance for each year. The table does not include the Hutch Sub project or Unit #1 purchases being funded by gas division cash. Table 3 revises YE cash balance in the gas division if cash is used from the NG division to pay for the Hutch Sub and Unit #1 purchase. Estimated project costs are $18.9M. Cash balances include rate increases. The tables show the Commissioners how the Natural Gas Division can fund the projects. Focusing on the Overall Combined Division, GM Carter looked at the Commissioners for questions. GM Carter reviewed the different Project Cash Flow Options. Option 1 — use cash balance to fund the remaining Hutch Sub project. GM Carter noted the relevance to the bond rating and if the Commission would be comfortable with cash reserves dipping below established reserves. Option 2 — restructure remaining natural gas debt $4.1 M over a long duration to free up cash over a couple of years. GM Carter noted the call options available for prepayment without penalty. Option 3 — issue new short-term debt $3M-$5M to cover cash potentially falling below reserves. GM Carter noted restricted reserve requirements increase. Option 4 — issue new longer -term debt. GM Carter noted some interest on long-term debt will not be recoverable through Annual Transmission Revenue Requirements (ATRR) and restricted reserve requirements increase. Option 5 — explore other financing options. Discussion was held on the cash flow tables and all the cash flow options along with issuing bonds with the intent to reimburse HUC for capital related project costs, in which case a bond resolution is needed, timeframe and several additional steps would need to take place. Commissioners agreed to use cash as a first option but directed GM Carter to work on a bond Resolution in case cash balances fall to an unacceptable level, HUC would then be in a position to issue short-term debt. Adjourn There being no further business, a motion by Commissioner Pullis, second by Commissioner Silvernale to adjourn the meeting at 2:49p.m. Motion carried unanimously. ATTEST: Matt Cheney, President 2 Don Martinez, Secretary Hutchinson City Council / Utilities Commission / Economic Development Authority Joint Meeting City Council Chambers 111 Hassan Street SE June 4, 2025 — 7:00 a.m. MINUTES I. Welcome / Call to Order — All boards called the meeting to order at 7:00 a.m. Council members present: Gary Forcier, Chad Czmowski, Pat May, Dave Sebesta; Staff — Matt Jaunich, Andy Reid EDA Board Members present: Jonny Block, Mike McGraw, Jack Daggett; Staff — Miles Seppelt HUC Members present: Matt Cheney, Troy Pullis, Tom Lambert, Kathy Silvernale, Don Martinez; Staff —Jeremy Carter II. Introductions All board members introduced themselves as well as other staff members in attendance. III. HUC Overview Jeremy Carter, HUC General Manager, presented before the group. Mr. Carter provided an update on current projects and upcoming projects. HUC's mission is to maintain reliable service and stable rates. Mr. Carter distributed data indicating HUC's position in the industry with competitive rates. Mr. Carter also reviewed how natural gas retail sales are handled. IV. City Overview Matt Jaunich, City Administrator, presented before the group. Mr. Jaunich provided a state of the city review including information on the unemployment rate, rental/housing data, building permit data, market value growth, tax rate trend and comparisons, and new developments that have recently occurred. Mr. Jaunich also reviewed efforts the City has completed to plan for the future such as the 2022 housing study, 2023 growth area plan, the 2024 downtown plan and the 2025 strategic plan which should be adopted this Summer. V. EDA Overview Miles Seppelt, EDA Director, presented before the group. Mr. Seppelt reviewed the EDA's mission which includes facilitating redevelopment, job creation and concentrating on manufacturing. Mr. Seppelt reviewed the importance of manufacturing facilities in communities. Mr. Seppelt also reviewed the strategies the EDA uses to retain and attract new businesses/companies to Hutchinson. Mr. Seppelt spoke about readiness being the key for new businesses to locate in Hutchinson. Valerie Mackenthun, Hutchinson Chamber and Visitors Bureau, presented before the group. Ms. Mackenthun spoke about the Chamber's focus of supporting local businesses and members, enhancing tourism, and community collaboration. Ms. Mackenthun also spoke about the revitalization of the Hutchinson Downtown Association. VI. Discussion: Diversifying the City's Commercial & Industrial Base / Future Directions Mr. Carter noted he wants to make sure that HUC is positioned for growth in the community however HUC needs to be made aware of the potential growth opportunities. He noted that HUC has received increased inquiries related to large technology companies and needing large load capacity. The demand for load is ramping up in the Midwest. Proximity to current substations for location of large load companies is an important consideration as building new substations takes time and money. Finding the next industrial park is important as well. Discussion of the value of extending infrastructure to the Hwy 7/22 intersection holds the highest potential for development of commercial/industrial businesses. HUC has infrastructure to that intersection so water/sewer would need to be extended. HUC spoke about the urging by their auditor of having a more diversified customer class in the commercial/industrial base related to electrical load. Some constraints for businesses locating/relocating to Hutchinson is not having big enough lots and location/proximity to a four - lane highway and/or rail line. Discussion was held regarding marketing the community and having spec buildings ready for potential businesses. VII. Next Steps The consensus of the group was that these three boards meet on an annual basis. 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Depreciation Transfers (Elect./City) Operating Expense Debt Interest TOTAL EXPENSES NET PROFIT/(LOSS) 41.6% of Year Comp. 2025 2024 Di %Chna 2025 2024 Di %Chna Full Yr Bud %of Bud $ 2,633,852 $ 2,469,702 $ 164,150 6.6% $ 15,761,954 $ 15,014,885 $ 747,069 5.0% $ 38,041,145 41.4% $ 316,300 $ 272,903 $ 43,397 15.9% $ 1,931,673 $ 1,501,133 $ 430,539 28.7% $ 3,490,250 55.3% $ 171,693 $ 98,111 $ 73,582 75.0% $ 857,365 $ 763,158 $ 94,207 12.3% $ 2,071,218 41.4% $ 60,639 $ 60,383 $ 255 0.4% $ 303,194 $ 301,917 $ 1,278 0.4% $ 727,666 41.7% $ 41,495 $ 37,435 $ 4,059 10.8% $ 229,443 $ 970,959 $ (741,516) (76.4%) $ 483,841 47.4% $ 36,541 $ 87,321 $ (50,780) (58.2%) $ 305,103 $ 420,178 $ (115,075) (27.4%) $ 633,457 48.2% $ 3,260,519 $ 3,025,855 $ 234,665 7.8% $ 19,388,732 $ 18,972,230 $ 416,502 2.2% $ 45,447,577 42.7% $ 640,685 $ 691,654 $ (50,970) (7.37%) $ 3,238,672 $ 3,301,723 $ (63,051) (1.9%) $ 8,248,534 39.3% $ 1,298,725 $ 1,188,816 $ 109,909 9.2% $ 8,887,102 $ 8,563,050 $ 324,052 3.8% $ 20,256,167 43.9% $ 282,290 $ 206,382 $ 75,908 36.8% $ 1,048,742 $ 946,166 $ 102,576 10.8% $ 3,015,064 34.8% $ 63,521 $ 20,194 $ 43,327 214.5% $ 415,898 $ 449,589 $ (33,691) (7.5%) $ 1,284,200 32.4% $ 349,270 $ 364,884 $ (15,615) (4.3%) $ 1,746,836 $ 1,823,292 $ (76,455) (4.2%) $ 4,310,000 40.5% $ 222,524 $ 222,269 $ 255 0.1% $ 1,112,622 $ 1,111,345 $ 1,277 0.1% $ 2,670,292 41.7% $ 237,951 $ 205,580 $ 32,371 15.7% $ 1,392,923 $ 1,385,389 $ 7,534 0.5% $ 3,174,901 43.9% $ 49,688 $ 58,538 $ (8,850) (15.1%) $ 248,440 $ 292,690 $ (44,250) 15.1% $ 596,257 41.7% $ 3,144,654 $ 2,958,318 $ 186,337 6.3% $ 18,091,236 $ 17,873,243 $ 217,992 1.2% $ 43,555,415 41.5% $ 115,865 $ 67,537 $ 48,328 71.6%1 1,297,496 $ 1,098,987 $ 198,509 18.1% $ 1,892,162 68.6% May May i, YTD YTD 2025 2024 Change 2025 2024 Change Gross Margin %: 36.2% 37.6% -1.4% 34.4% 32.5% 1.9% Operating Income Per Revenue $ (%): 3.3% 0.7% 2.7% 5.9% 0.5% 5.4% Net Income Per Revenue $ (%): 3.6% 2.2% 1.3% 6.7% 5.8% 0.9% 2025 HUC Budget Target 34.2% 3.5%N 4.2%N uuIIUuIINNI HUTCHINSON UTILITIES COMMISSION ELECTRIC DIVISION FINANCIAL REPORT FOR MAY, 2025 41.6% of Year Comp. 2025 2024 Di . %Chna 2025 2024 Di %Chna Full YrBud %of Bud Electric Division Customer Revenue $ 1,983,168 $ 1,881,280 $ 101,887 5.4% $ 9,623,444 $ 9,108,006 $ 515,439 5.7% $ 25,609,217 37.6% Sales for Resale $ 316,300 $ 272,903 $ 43,397 15.9% $ 1,931,673 $ 1,501,133 $ 430,539 28.7% $ 3,490,250 55.3% Other Revenues $ 16,475 $ 14,101 $ 2,373 16.8% $ 96,788 $ 91,744 $ 5,044 5.5% $ 191126 50.6% Interest Income $ 19,665 $ 45,055 $ (25,390) (56.4%) $ 159,522 $ 217,059 $ (57,538) (26.5%) $ 333:457 47.8% TOTAL REVENUES $ 2,335,607 $ 2,213,339 $ 122,268 5.5% $ 11,811,426 $ 10,917,942 $ 893,485 8.2% $ 29,624,050 39.9% Salaries & Benefits $ 472,795 $ 506,865 $ (34,069) (6.7%) $ 2,454,952 $ 2,463,205 $ (8,253) (0.3%) $ 5,955,489 41.2% Purchased Power $ 915,946 $ 896,045 $ 19,900 2.2% $ 4,873,873 $ 4,546,301 $ 327,573 7.2% $ 12,605,893 38.7% Transmission $ 282,290 $ 206,382 $ 75,908 36.8% $ 1,048,742 $ 946,166 $ 102,576 10.8% $ 3,015,064 34.8% Generator Fuel/Chem. $ 63,521 $ 20,194 $ 43,327 214.5% $ 415,898 $ 449,589 $ (33,691) (7.5%) $ 1,284,200 32.4% Depreciation $ 251,485 $ 271,621 $ (20,136) (7.4%) $ 1,257,897 $ 1,358,182 $ (100,285) (7.4%) $ 3,200,000 39.3% Transfers (Elect./City) $ 172,789 $ 172,534 $ 255 0.1% $ 863,945 $ 862,668 $ 1,277 0.1% $ 2,073,468 41.7% Operating Expense $ 148,680 $ 125,282 $ 23,398 18.7% $ 891,502 $ 921,588 $ (30,086) (3.3%) $ 2,145,148 41.6% Debt Interest $ 32,771 $ 35,305 $ (2,533) (7.2%) $ 163,857 $ 176,523 $ (12,667) JLZLI $ 393,257 41.7% TOTAL EXPENSES $ 2,340,278 $ 2,234,228 $ 106,051 4.7% $ 11,970,666 $ 11,724,222 $ 246,444 2.1% $ 30,672,519 39.0% NET PROFIT/(LOSS) $ (4,671) $ (20,889) $ 16,218 (77.6%) $ (159,239) $ (806,280) $ 647,041 (80.3%) $ (1,048,469) 15.2% 41.6% of Year Comp. 2025 2024 Di . %Chna 2025 2024 Di %Chna Full YrBud %of Bud Electric Division Residential 4,017,225 3,762,341 254,884 6.77% 20,383,624 19,590,333 793,291 4.05% 54,084,350 37.7% All Electric 121,278 106,005 15,273 14.41% 1,212,794 1,062,788 150,006 14.11% 2,585,300 46.9% Small General 1,360,833 1,317,161 43,672 3.32% 7,241,747 6,920,352 321,395 4.64% 18,348,996 39.5% Large General 7,901,110 6,357,040 1,544,070 24.29% 34,018,840 29,865,243 4,153,597 13.91% 83,540,973 40.7% Industrial 8,518,000 9,541,000 (1,023,000) (10.72%) 40,838,000 44,171,000 (3,333,000) (7.55%) 113,841,379 35.9% Total KWH Sold 21,918,446 21,083,547 834,899 3.96% 103,695,005 101,609,716 2,085,289 2.05%1 272,400,998 38.1% May May YTD YTD 2025 HUC 2025 2024 Change 2025 2024 Change Budget Target Gross Margin %: 30.2% 30.6% -0.4% 28.9% 27.1% 1.7% 27.0% Operating Income Per Revenue $ (%): 0.3% -1.5% 1.7% -1.5% -8.2% 6.7% -3.5% 0%- 1% Net Income Per Revenue $ (%): -0.2% -0.9% 0.7% -1.3% -7.4% 6.0% -3.5% 0%- 1% Customer Revenue per KWH: $0.0905 $0.0892 $0.0012 $0.0928 $0.0896 $0.0032 $0.0940 $0.0940 Total Power Supply Exp. per KWH: $0.0737 $0.0713 $0.0023 $0.0797 $0.0765 $0.0032 $0.0784 $0.0784 Net Loss decreased by $16,218 over May 2024. Usage and revenue were up but offset by higher transmission and purchased power expenses. Sales for Resale of $316,300 consisted of $72,050 in market sales, $98,000 in capacity sales to Rice Lake, and $146,250 in capacity sales to AEP. May 2024 Sales for Resale of $272,903 included $28,653 in market sales, $98,000 in capacity sales to Rice Lake, $146,250 in capacity sales to AEP. May 2023 Sales for Resale of $535,359 consisted of $58,252 in market sales, $98,000 in capacity sales to Rice Lake, $146,250 in capacity sales to AEP, and $232,857 in tolling and energy sales to Dynasty Power. Overall Purchased Power increased by $19,900. MRES purchases increased by $27,330 and market purchases/MISO costs decreased by $7,430. The average cost of MISO power was $32.00/mwh (2,206 mwh's purchased), compared to $20.61/mwh (2,764 mwh's purchased) in May 2024. There was no Power Cost Adjustment for May 2025 leaving the total at $151,798 YTD. $91,121 was added to the rate stabilization fund with the market sales. There was no PCA in May 2024 or YTD 2024. Gas Division Customer Revenue Transportation Electric Div. Transfer Other Revenues Interest Income TOTAL REVENUES Salaries & Benefits Purchased Gas Operating Expense Depreciation Transfers (City) Debt Interest TOTAL EXPENSES NET PROFIT/(LOSS) HUTCHINSON UTILITIES COMMISSION GAS DIVISION FINANCIAL REPORT FOR MAY, 2025 41.6% of Year Comp. 2025 2024 2 %Chna 2025 2024 2 . %Chna Full Yr Bud % of Bud $ 650,685 $ 588,421 $ 62,263 10.6% $ 6,138,510 $ 5,906,879 $ 231,631 3.9% $ 12,431,928 49.4% $ 171,693 $ 98,111 $ 73,582 75.0% $ 857,365 $ 763,158 $ 94,207 12.3% $ 2,071,218 41.4% $ 60,639 $ 60,383 $ 255 0.4% $ 303,194 $ 301,917 $ 1,278 0.4% $ 727,666 41.7% $ 25,020 $ 23,334 $ 1,686 7.2% $ 132,655 $ 879,216 $ (746,560) (84.9%) $ 292,715 45.3% $ 16,877 $ 42,266 $ (25,390) (60.1%) $ 145,581 $ 203,119 $ (57,538) (28.3%) $ 300,000 48.5% $ 924,912 $ 812,516 $ 112,396 13.8% $ 7,577,305 $ 8,054,288 $ (476,983) (5.9%) $ 15,823,527 47.9% $ 167,889 $ 184,790 $ (16,900) (9.1%) $ 783,720 $ 838,518 $ (54,798) (6.5%) $ 2,293,045 34.2% $ 382,779 $ 292,771 $ 90,009 30.7% $ 4,013,229 $ 4,016,749 $ (3,520) (0.1%) $ 7,650,274 52.5% $ 89,270 $ 80,298 $ 8,973 11.2% $ 501,421 $ 463,801 $ 37,621 8.1% $ 1,029,753 48.7% $ 97,785 $ 93,263 $ 4,522 4.8% $ 488,940 $ 465,110 $ 23,830 5.1% $ 1,110,000 44.0% $ 49,735 $ 49,735 $ (0) (0.0%) $ 248,677 $ 248,677 $ (0) (0.0%) $ 596,824 41.7% $ 16,917 $ 23,233 $ (6,317) 0.0% $ 84,583 $ 116,167 $ (31,583) 27.2% $ 203,000 41.7% $ 804,376 $ 724,090 $ 80,286 11.1% $ 6,120,570 $ 6,149,021 $ (28,451) (0.5%) $ 12,882,896 47.5% $ 120,536 $ 88,426 $ 32,110 36.3%1 1,456,736 $ 1,905,267 $ (448,532) (23.5%) $ 2,940,631 49.5% I�i�(( (f�1��iiii�� Ii �i I �� ll�i��fri f�(�i ��iii�� 41.6% of Year Comp. 2025 2024 2 . %Chnq 2025 2024 p %Chnq Full Yr Bud % of Bud Gas Division Residential 13,891,946 10,447,071 3,444,875 32.97% 252,622,461 214,515,663 38,106,798 17.76% 435,250,000 58.0% Commercial 12,179,973 10,862,725 1,317,248 12.13% 181,665,532 153,707,166 27,958,366 18.19% 337,584,000 53.8% Industrial 53,176,734 49,327,407 3,849,327 7.80% 402,514,253 366,657,916 35,856,337 9.78% 895,764,000 44.9% Total CF Sold 79,248,653 70,637,203 8,611,450 12.19% 836,802,246 734,880,745 101,921,501 13.87 11,668,598,000 50.2% May May YTD YTD 2025 2025 2024 Change 2025 2024 Change Budget Gross Margin %: 51.8% 57.8% -6.0% 43.2% 40.7% 2.5% 48.0% Operating Income Per Revenue $ (%): 11.3% 6.8% 4.5% 17.6% 13.8% 3.8% 17.0% Net Income Per Revenue $ (%): 13.0% 10.9% 2.1% 19.2% 23.7% -4.4% 18.6% Contracted Customer Rev. per CF: $0.0065 $0.0058 $0.0007 $0.0067 $0.0071 -$0.0004 $0.0061 Customer Revenue per CF: $0.0112 $0.0134 -$0.0023 $0.0079 $0.0089 -$0.0010 $0.0087 Total N.G. Supply Exp. per CF: $0.0054 $0.0045 $0.0009 $0.0050 $0.0056 ($0.0007) $0.0048 Notes/Graphs: May Net Income increased by $32,110. Usage and revenue were up but were offset by higher purchased gas costs with the increased usage. May 2025 Fuel Credit Adjustment was $1.307/MCF crediting customers $37,671 for the month and $494,864 YTD. There was no May 2024 FCA but $150,146 was returned to customers YTD. HUC Target $0.0087 $0.0048 HUTCHINSON UTILITIES COMMISSION BALANCE SHEET - CONSOLIDATED MAY31, 2025 Electric Gas Total Total Net Change Division Division 2025 2024 Total (YTD) Current Assets UnrestrictedlUndesignated Cash Cash (1,642,614.35) 14,562,090.33 12,919,475.98 15,731,354.50 (2,811,878.52) 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 840,953.15 - 840,953.15 398,808.13 442,145.02 Rate Stabilization - Gas - 615,294.19 615,294.19 583,207.88 32,086.31 Catastrophic Funds 800,000.00 200,000.00 1,000,000.00 1,000,000.00 - Restticted Cash Bond & Interest Payment 2017 395,399.99 - 395,399.99 591,828.12 (196,428.13) Bond & Interest Payment 2012 - 989,999.98 989,999.98 1,086,900.00 (96,900.02) 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 5,673,476.79 19,736,378.50 25,409,855.29 28,041,230.63 (2,631,375.34) Receivables Accounts (net of uncollectible allowances) 1,910,929.04 621,382.52 2,532,311.56 2,594,593.69 (62,282.13) Interest 74,314.28 74,314.29 148,628.57 141,412.63 7,215.94 Total Receivables 1,985,243.32 695,696.81 2,680,940.13 2,736,006.32 (55,066.19) Other Assets Inventory 2,058,352.14 537,237.61 2,595,589.75 2,558,961.95 36,627.80 Prepaid Expenses 308,051.53 56,203.08 364,254.61 615,995.30 (251,740.69) Sales Tax Receivable 412,360.43 - 412,360.43 351,105.72 61,254.71 Deferred Outflows- Electric 342,759.00 - 342,759.00 741,556.00 (398,797.00) Deferred Outflows - Gas - 114,253.00 114,253.00 247,185.00 (132,932.00) Total Other Assets 3,121,523.10 707,693.69 3,829,216.79 4,514,803.97 (685,587.18) Total Current Assets 10,780,243.21 21,139,769.00 31,920,012.21 35,292,040.92 (3,372,028.71) Capital Assets Land & Land Rights 690,368.40 3,899,918.60 4,590,287.00 4,590,287.00 - Depreciable Capital Assets 94,055,127.09 44,579,509.55 138,634,636.64 157,413,821.64 (18,779,185.00) Accumulated Depreciation (49,487,975.25) (22,742,040.98) (72,230,016.23) (93,471,029.00) 21,241,012.77 Construction - Work in Progress 3,678,079.33 97,025.64 3,775,104.97 3,105,702.22 669,402.75 Total Net Capital Assets 48,935,599.57 25,834,412.81 74,770,012.38 71,638,781.86 3,131,230.52 Total Assets 59,715,842.78 46,974,181.81 106,690,024.59 106,930,822.78 (240,798.19) 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 MAY31, 2025 Electric Gas Total Division Division 2025 790,000.00 19, 546.00 2,633,194.96 126,515.80 3,569,256.76 11,750,000.00 418,212.00 1,832,248.00 39,880.00 569,807.22 208,347.54 1,294,449.00 16,112,943.76 1,980,000.00 185,608.32 691,394.33 46,284.72 2,903,287.37 2,080,000.00 92,803.79 610,749.00 13,293.00 169,522.80 37,374.19 431,483.00 3,435,225.78 2,770,000.00 185,608.32 19, 546.00 3,324,589.29 172,800.52 6,472,544.13 11,750,000.00 2,080,000.00 511,015.79 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 19,548,169.54 Total Net Change 2024 Total (YTD) 2, 655, 000.00 115, 000.00 185,608.32 - - 19,546.00 2,723,174.80 601,414.49 167,179.39 5,621.13 5,730,962.51 741,581.62 12,540,000.00 (790,000.00) 4,060,000.00 (1,980,000.00) 730,081.07 (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 23,321,639.44 (3,773,469.90) 40,033,642.26 40,635,668.66 80,669,310.92 77,878,220.83 2,791,090.09 40,033,642.26 40,635,668.66 80,669,310.92 77,878,220.83 2,791,090.09 Total Liabilities and Net Position 59,715,842.78 46,974,181.81 106,690,024.59 106,930,822.78 (240,798.19) Hutchinson Utilities Commission Cash -Designations Report, Combined 5/31/2025 Financial Institution Current Interest Rate Annual Interest Balance, May 2025 Balance, April 2025 Change in Cash/Reserve Position Savings, Checking, Investments varies varies varies 25,409,855.29 25,309,949.86 99,905.43 Total Operating Funds 25,409,855.29 25,309,949.86 99,905.43 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) 1,385,399.97 1,403,006.74 (17,606.77) 3,255,256.00 3,255,256.00 4,640,655.97 4,658,262.74 (17,606.77) 6,542,569.17 6,542,569.17 - 1,456,247.34 1,365,126.60 91,120.74 1,942,626.00 1,942,626.00 - 1, 000, 000.00 1, 000, 000.00 3,450,000.00 3,450,000.00 - 14,391,442.51 14,300,321.77 91,120.74 YE YE YE YE YTD HUC 2021 2022 2023 2024 2025 Target Debt to Asset 30.8% 31.4% 28.6% 26.0% 24.4% Current Ratio 5.22 4.47 4.48 3.67 4.16 RONA 0.41% -1.38% 1.96% 2.63% 1.36% Change in Cash Balance (From 12131114 to 513112025) Month End Electric Elec. Change Natural Gas Gas Change Total Total Change 5/31/2025 5,673,477 19,736,379 25,409,855 12/31/2024 6,134,710 (461,234) 17,717,453 2,018,925 23,852,164 1,557,692 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 5/31/2025 Change in Financial Annual Balance, Balance, Cash/Reserve Institution Current Interest Rate Interest May 2025 April 2025 Position �' Rr Savings, Checking, Investments varies varies varies 25,409,855.29 25,309,949.86 99,905.43 Total HUC Operating Funds 25,409,855.29 25,309,949.86 99,905.43 Debt Restricted Requirements Debt Restricted Requirements Total Restricted Funds Bond Covenants - sinking fund Bond Covenants -1 year Max. P & 1 395,399.99 1,183,256.00 1,578,655.99 493,423.43 1,183,256.00 1,676,679.43 (98,023.44) (98,023.44) Excess Reserves Less Restrictions, Electric :0 i 11J! !!1 1 !1 J J Operating Reserve Min 60 days of 2025 Operating Bud. 4,578,753.17 4,578,753.17 - Rate Stabalization Funds $400K-$1.2K 840,953.15 749,832.41 91,120.74 PILOT Funds Charter (Formula Only) 1,345,802.00 1,345,802.00 - Catastrophic Funds Risk Mitigation Amount 800,000.00 800,000.00 Capital Reserves 5 Year CIP (2025-2029 Fleet & Infrastructure Maintenance) 2,750,000.00 2,750,000.00 - Total Designated Funds 10,315,508.32 10,224,387.58 91,120.74 Excess Reserves Less Restrictions & Designations, Electric (6,220,687.52) (5,925,351.34) (295,336.18) YE YE YE YE YTD APPA Ratio HUC 2021 2022 2023 2024 2025 5K-10K Cust. Target Debt to Asset Ratio (* w/Gen.) 32.2% 34.8% 34.0% 33.9% 33.0% 39.8% pp ppppp ryry NNNNNNNNNNNN Current Ratio 5.70 4.96 4.35 2.38 2.48 3.75 RONA -1.2% -4.2% -0.9% -2.1% -0.3% NA >0% Hutchinson Utilities Commission Cash -Designations Report, Gas 5/31/2025 Change in Financial Annual Balance, Balance, Cash/Reserve Institution Current Interest Rate Interest May 2025 April 2025 Position F�' Rr Savings, Checking, Investments varies varies varies 25,409,855.29 25,309,949.86 99,905.43 Total HUC Operating Funds 25,409,855.29 25,309,949.86 99,905.43 Debt Restricted Requirements Bond Covenants - sinking fund 989,999.98 909,583.31 80,416.67 Debt Restricted Requirements Bond Covenants -1 year Max. P & 1 2,072,000.00 2,072,000.00 - Total Restricted Funds 3,061,999.98 2,981,583.31 80,416.67 Excess Reserves Less Restrictions, Gas 16,674,378.52 16,352,650.88 321,727.64 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% 13.5% 35%-50% Current Ratio 4.79 4.06 4.61 5.08 6.19 1.0-3.0 RONA 2.9% 3.0% 6.2% 9.1% 3.6% 2%-5% Notes/Graphs: ELECTRIC DIVISION Operating Revenue May 2025 CLASS AMOUNT KWH /KWH Street Lights $20.22 371 $0.0545 Electric Residential Service $456,734.16 4,017,225 $0.1137 All Electric Residential Service $14,797.60 121,278 $0.1220 Electric Small General Service $146,758.78 1,360,833 $0.1078 Electric Large General Service $710,774.00 7,901,110 $0.0900 Electric Large Industrial Service $654,082.90 8,518,000 $0.0768 Total $1,983,167.66 21,918,817 $0.0905 Power Adjustment $0.00000 Rate Without Power Adjustment $0.09048 Electric Division Year -to -Date ® 2025 $ Amount ❑ 2024 $ Amount ® 2025 KWH110 ❑ 2024 KWH110 14,000,000 12,000,000 10,000,000 8,000,000 6,000,000 4,000,000 2,000,000 0 EM 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 May 2025 CLASS AMOUNT MCF /MCF Residential $176,627.58 13,892 $12.7144 Commercial $125,330.23 12,180 $10.2899 Large Industrial $19,263.71 2,680 $7.1887 Large Industrial Contracts $329,463.00 50,497 $6.5244 Total $650,684.52 79,249 $8.2107 Fuel Adjustment-$1.30700 Rate Without Fuel Adjustment $9.51767 Natural Gas Division Year -to -Date ❑ 2025 $ Amount ❑ 2024 $ Amount m 2025 MCF ❑ 2024 MCF 7,000,000 6,000,000 5,000,000 4,000,000 3,000,000 2,000,000 1,000,000 0 on Gas Residential Gas Commercial Large Industrial Large Industrial Total Contracts W Z E E P a a N R W U R a C e 7i U N N N N N N O N N N O N N N Q Q Q Q Q O O O O O O E Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q O Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q Q- Q Q\ Q O\ Q Q Q O\ N_ N N N Z Z Z Z Z N O O 0M 0M N C Z Z Z Z Z Z Z Z Z Z Z Z Z Z M Z O Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z Z O Z ?j Z o Z Z� Z Z Z o I W .0 (O (O .0Q CO r N m m W 000000 O O O O O 0 W M W 0 0 O�0 m OWOW�OOOr O� V WM V I�� V (00000 �R V NCO I� W �O� I� MO ��r� ON N�- WI�O(00 W (( � � m �� W O MW N M W� (0r0 r 0O Vr OO m V0000NMMMN� wm W M�0m NW 0 W W .-`� W 1R 0 V G00 00 V 0 V'tm't' 00 wG 0 CO O0 0O N COO W W I�� M W 00 0000� O �(000000 V O (0(0c)W 0l)0)O(0M0 O (0 (01—(06�00� M W � V 0 V V NM W N W I- NO �O � � MN M�M6� ON NCO W�O(0 ��I�VMO�(0�6�(OWNLoOI-WMMONM0 M NN ONE V V N 06� W 6�M 00 COM V V I�I� ON NIA 0 W W O �VI�W ON �I� MW�O WOrOOMNWM N00WWMW0 N W.-NO6� NCO CO V N V V I� W NN 6�C0 N I� I� COOON6�� 6�C01�C06� co CON N N NM W W�6� CON 000�00 (O�MNWMVcomI V-N.'M.'(OW--(o M-,,I- a; 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N O O O O O N O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O o O W O O O N O Ol O W O O I� lD o Vf o a O O M N o ei N O n O M 00 Ln M M fl 3: > y M O ro OD C a — C O M � c O CO � � O V o0 ei `m > v o R 0 0 0 0 0 C (a e O 00 00 00 O O '2 y w F N N Lo O E E N y7 (O M O O 7 O) O) La W u 7 N R V N O M N O) 00 (7 N> N o0 M 00 M R V N O o0 Ln N O 00 La In r 00 N (M Lo O M 0. N f o 0 0 0 0 O V o0 00 00 O O o F N V O 0o M Lo O N m- O M M (O a) I o O R N V O) O) (O O V (O 00 M R O) I6 00 00 M M D M N O) O cq d N a J Y O 7 -O m 0 ~ O ca a E .2 a w MMFIFI HUTCHINSON UTILITIES COMMISSION 9T, Board Action Form iiiiiiiiiiiiiiiiiiiiiillillillillillillilliillillillillillillilliilliillillillillillillillillillilliillillillillillillilliillillillillillillilliillillillillillillillillillillilliillillillillillillilliillillillillillillilliillillillillillillillillillillilliillillillillillillilliillillillillillillilliillillillillillillillillillillilliillillillillillillilliillillillillillillilliillillillillillillillillillillilliillillillillillillilliillillillillillillilliillillillillillillillillillillilliillillillillillillilliillillillillillillilliillillillillillillillillillillilliillillillillillillilliillillillillillillilliillillillillillillillillillillilliillillillillillillilliillillillillillillilliillillillillillillillillillillilliillillillillillillilliillillillillillillilliillillillillillillillillillillilliillillillillillillilliillillillillillillilliillillillillillillillillillillilliillillillillillillilliillillillillillillilliillillillillillillillillillillilliillillillillillillilliillillillillillillilliilllI 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 6 of Exempt Handbook ii. Section 6 of Non -Exempt Handbook BOARD ACTION REQUESTED: None Fiscal Impact: Included in current budget: Budget Change: PROJECT SECTION: Total Project Cost: Remaining Cost: Exempt EMPLOYEE RIGHT -To -KNOW Minnesota's Employee Right -to -Know law requires HUC to inform employees when they may be exposed to hazardous substances, harmful physical agents, or infectious agents. HUC has adopted a written Employee Right -to -Know program. HUC has evaluated and reevaluates the work sites to determine the presence of hazardous substances. Employees shall become familiar with the location of Safety Data Sheets (SDS) in their work area. Non -Exempt EMPLOYEE RIGHT -To -KNOW Minnesota's Employee Right -to -Know law requires HUC to inform employees when they may be exposed to hazardous substances, harmful physical agents, or infectious agents. HUC has adopted a written Employee Right -to -Know program. HUC has evaluated and reevaluates the work sites to determine the presence of hazardous substances. Employees shall become familiar with the location of Safety Data Sheets (SDS) in their work area. PRESCRIPTION SAFETY GLASSES Employees must pay for their own eye examination (health insurance will generally cover 100% of examination expense). Any supplier who can provide certification that the prescription glasses meet OSHA safety requirements may fill the prescription. HUC will reimburse full-time employees up to $150.00, once every 12 months. Contact the Administrative/HR Coordinator for information regarding the Safety Glasses program, forms, and participating vendors. 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. Accidents and Injuries (Exempt and Non -Exempt) ii. Unsafe Conditions or Practices (Exempt and Non -Exempt) iii. Protected Safety Footwear (Exempt and Non -Exempt) BOARD ACTION REQUESTED: Approve Policy Changes Fiscal Impact: Included in current budget: Budget Change: PROJECT SECTION: Total Project Cost: Remaining Cost: Exempt SECTION 6 - HEALTH AND SAFETY HUC is very concerned about the safety of its employees and the public HUC serves. All employees are required to follow all HUC safety rules and make the safety of themselves, their co- workers, and the public a priority. To encourage a safe workplace, the Commission has adopted the APPA — Utilities Safety Handbook. Compliance with the APPA is "mandatory and is considered a requirement for employment". ACCIDENTS AND INJURIES Employees must immediately report to a Di Feee�oF.,..-Manager or Supervisor job -related illnesses, all accidents and injuries (regardless how minor) that occur during the course of employment with HUC. The Employee and Supervisor must fill out and sign an accident report. If a supervisor is not available and the nature of injury or illness requires immediate treatment, the employee is to go to the nearest available medical facility for treatment and, as soon as possible, notify his/her supervisor of the action taken. In the case of a serious emergency, 911 should be called. If the injury is not of an emergency nature, but requires medical attention, the employee will report it to the supervisor and make arrangements for a medical appointment. Worker's compensation benefits and procedures to return to work will be applied according to applicable state and federal laws. Workers Compensation insurer is League of Minnesota Cities Insurance Trust (LMCIT). Pursuant to Minnesota Law, HUC has established a labor-management safety committee that investigates or reviews all accidents to identify causes of the accidents and suggest ways to prevent reoccurrence of the accident. The safety committee may request to interview any employee involved in an accident or any employee who may have knowledge of an accident. All employees are required to cooperate with the safety committee. UNSAFE CONDITIONS OR PRACTICES Employees are required to report to a i::.� fee.�of Manager or Supervisor any unsafe conditions or practices they observe, including failure of a co-worker to follow safety rules or procedures. PROTECTED SAFETY FOOTWEAR The following footwear must be purchased by the Employee and the paid receipt submitted for reimbursement by HUC. HUC will reimburse the lessor of the actual purchase price or the maximum amount indicated within this policy. The type and/or need must be approved by the department manager/director prior to purchase and reimbursement. Protective footwear purchased with these funds must meet OSHA and uniform policy requirements for the individual's regular job duties according to APPA section 405 Wearing Apparel. The original receipt must be submitted with all reimbursement requests. Safety Toed Boots and Shoes - Employees are highly encouraged to purchase quality footwear for their own protection and comfort. HUC will reimburse employees based on the following criteria: • Up to $250 for full-time employees, once every 12 months • Up to $250 for Seasonal and Temporary employees, once every 3 years Insulated Safety Toed Winter Boots — The need for insulated boots must be approved by the department manager/director. HUC will reimburse employees based on the following criteria: • Up to $250 for full-time employees, once every 3 years Should an employee's protective footwear become damaged or in excessively poor condition, the employee would be eligible for replacement footwear provided that the department manager/4.4eec of determines the footwear was damaged or in excessively worn condition due to the employee performing their assigned work duties. When replacing damaged or excessively worn protective footwear, the same maximum reimbursement amounts shall apply. Non -Exempt SECTION 6 — HEALTH AND SAFETY HUC is very concerned about the safety of its employees and the public HUC serves. All employees are required to follow all HUC safety rules and make the safety of themselves, their co- workers, and the public a priority. To encourage a safe workplace, The Commission has adopted the APPA — Utilities Safety Handbook. Compliance with the APPA is "mandatory and is considered a requirement for employment". ACCIDENTS AND INJURIES Employees must immediately report to a DiFeeF Manager or Supervisor job -related illnesses, all accidents and injuries (regardless how minor) that occur during the course of employment with HUC. The Employee and Supervisor must fill out and sign an accident report. If a supervisor is not available and the nature of injury or illness requires immediate treatment, the employee is to go to the nearest available medical facility for treatment and, as soon as possible, notify his/her supervisor of the action taken. In the case of a serious emergency, 911 should be called. If the injury is not of an emergency nature, but requires medical attention, the employee will report it to the supervisor and make arrangements for a medical appointment. Worker's compensation benefits and procedures to return to work will be applied according to applicable state and federal laws. Workers Compensation insurer is League of Minnesota Cities Insurance Trust (LMCIT). Pursuant to Minnesota Law, HUC has established a labor-management safety committee that investigates or reviews all accidents to identify causes of the accidents and suggest ways to prevent reoccurrence of the accident. The safety committee may request to interview any employee involved in an accident or any employee who may have knowledge of an accident. All employees are required to cooperate with the safety committee. UNSAFE CONDITIONS OR PRACTICES Employees are required to report to a i::.� fee.�(:*...(:)F Manager any unsafe conditions or practices they observe, including failure of a co-worker to follow safety rules or procedures. PROTECTED SAFETY FOOTWEAR The following footwear must be purchased by the Employee and the paid receipt submitted for reimbursement by HUC. HUC will reimburse the lessor of the actual purchase price or the maximum amount indicated within this policy. The type and/or need must be approved by the department manager/director prior to purchase and reimbursement. Protective footwear purchased with these funds must meet OSHA and uniform policy requirements for the individual's regular job duties according to APPA section 405 Wearing Apparel. The original receipt must be submitted with all reimbursement requests. Safety Toed Boots and Shoes - Employees are highly encouraged to purchase quality footwear for their own protection and comfort. HUC will reimburse employees based on the following criteria: • Up to $250 for full-time employees, once every 12 months • Up to $250 for Seasonal and Temporary employees, once every 3 years Insulated Safety Toed Winter Boots — The need for insulated boots must be approved by the department manager/director. HUC will reimburse employees based on the following criteria: • Up to $250 for full-time employees, once every 3 years Should an employee's protective footwear become damaged or in excessively poor condition, the employee would be eligible for replacement footwear provided that the department manager/4.4eec of determines the footwear was damaged or in excessively worn condition due to the employee performing their assigned work duties. When replacing damaged or excessively worn protective footwear, the same maximum reimbursement amounts shall apply. HUTCHINSON UTILITIES COMMISSION ^I'�xP61Tti'°" Board Action Form Agenda Item: Approve Req#010270 - Close interval Survey Presenter: Byron Bettenhausen Agenda Item Type: Time Requested (Minutes): 5 New Business Attachments: Yes BACKGROUND/EXPLANATION OFAGENDA ITEM: Lake Superior Consulting, LLC was requested to provide a quote to complete approximately 20-miles of interrupted close interval survey (CIS) for the Hutchinson Utilities Commission A close interval survey is conducted on pipelines to assess the entire structure's cathodic protection status by recording the pipe -to -soil potential profile. What sets a close interval survey apart from other surveys is it communicates the protection levels along the entire structure, rather than just sections or specific points on it. They identify otherwise hidden risk areas so that the issues can be resolved and prevented from becoming larger. The surveys are typically performed at the system's inception to act as a starting line of information. Surveys are typically completed every five years to compare the data to look for early signs of corrosion or other issues. This is the industry standard for transmission lines. It can be done more frequent if issues arise but the 5 year mark is industry best practice. Our transmission line has been in service for over 20 years and we have never done this type of survey. Our goal would be to complete 1/5 of our Transmission line annually going forward (20 miles each year). see packet for both bids. Cost of Project: CIS survey 20 miles of transmission line $27,580 Management of the reporting and survey results $2,839 BOARD ACTION REQUESTED: Approve Req# 010270 Fiscal Impact: $30,419 Included in current budget: No 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 PURCHASE REQUISITION HUTCHINSON UTILITIES COMMISSION 225 MICHIGAN ST SE HUTCHINSON, MN 55350 Phone:320-587-4746 Fax:320-587-4721 LAKE SUPERIOR CONSULTING LLC 130 W SUPERIOR ST STE 500 DULUTH, MN 55802 Note Description: CIS survey transmission line Date Requisition No. 06/10/2025 010270 Required by: 06/16/2025 Requested by: bbettenhausen Item No. Part No. Description Qty Unit Due Date Unit Price Ext. Amount CIS SURVEY 20 MILES OF TRANSMISSION LINE - MFG. 1 PART: 1.00 $27,580.000 $27,580.00 MANAGMENT AND REPORTING OF SURVEY RESULT - 2 MFG. PART: 1.00 $2,839.000 $2,839.00 Total: 30,419.00 Date Printed: 06/18/2025 Requisitioned By: bbettenhausen Page: 1/1 LADE SUPERIOR CONSULTING PROPOSAL 2025 Close Interval Survey LSC Project #: 76925250617 April 16, 2025 CLIENT INFORMATION Client Hutchinson Utilities Commission LSC INFORMATION Department: Integrity Management Point of Contact: Bryce Rusch Project Manager: Ben Frings Point of Contact 320.583.9146 Project Manager 218.256.1183 Phone Number: Phone Number: PROJECT INFORMATION Project Location: Hutchinson, MN Travel Required: Yes PROJECT SCHEDULE Estimated Project Start: May 5, 2025 Estimated Project End: June 30, 2025 PROJECT SCOPE AND WORK PLAN Lake Superior Consulting, LLC (LSC) was requested to provide a quote to complete approximately 20-miles of interrupted close interval survey (CIS) for the Hutchinson Utilities Commission (Hutchinson). The following points describe LSC's general scope and work plan as part of this project: • LSC will mobilize experienced technicians, led by an AMPP-certified CP1 technician at a minimum, to the project site and begin onsite work immediately upon arrival. • All CIS will be completed in accordance with AMPP SP0207. • Each CP system will be interrupted on a 12-second ON/4-second OFF, or 9-second ON/3-second OFF cycle for the duration of survey each day. No other cycle will be used without prior approval. o Prior to commencing CIS data collection, a direct current (DC) waveform will be recorded at various locations and analyzed to ensure synchronized interruption and to check for the presence of dynamic influence and capacitance. Waveforms will be recorded throughout the day to ensure quality CIS data is collected. • Stationary data loggers (SDLs) will be placed upstream, downstream, or within the survey segment as a means of quality control to monitor for interruption changes and dynamic influence throughout the survey duration. o A minimum of one SDL will be used during all survey. o Data collected can also be reviewed to identify dynamic influence from foreign sources, as well as compensate for telluric current influence if encountered. • Pipe -to -soil (P/S) potential data will be obtained using the Allegro Data Logger with a backpack capable of auto- chainage, a direct metallic contact to the pipeline, and calibrated CU/CUSO4 reference electrodes. o The OFF -delay time will be set such that reads are collected prior to significant depolarization. Reads will not be collected during any identified spiking. o AMPP SP0169 instant -OFF criteria will be utilized. o Copper Copper -Sulfate reference electrodes will be used. They will be calibrated each day prior to survey execution in accordance with AMPP TM0497. All surveys will be executed with reference cells that are within 10 mV. • ON and OFF P/S potentials will be taken at 10-foot intervals, directly over the pipeline when possible. Offset reads will be collected as necessary and documented as such. Project # 76925250617 2025 Close Interval Survey Page 1 o All areas along the pipeline will be surveyed unless physically impassible areas are encountered. These could include waterways more than knee-deep, paved roads, and high fences. o If depth of cover decreases to a point where a shorter spacing is required, LSC will adjust survey spacing to 5-foot intervals. • Depth of cover measurements will be gathered at intervals not to exceed 100 feet. • To ensure accurate data alignment, GPS equipment will be used to record every P/S potential measurement corresponding with the Allegro Data Logger. • When encountered, changes in direction of the pipeline (PI), terrain, aboveground appurtenances, road centerlines, line markers, fences, foreign line crossings, buildings, etc. will be documented in the data logger with GPS location. • Each P/S potential measurement will be recorded with a preset delay from the time the current interrupter switches on and off to avoid inaccurate measurements resulting from anodic and/or cathodic voltage spiking. • Upon completing a survey section and whenever possible, the surveyor will obtain the far -ground reading, near - ground reading, alternating current voltage on the pipeline, and IR drop between test points. Any applicable casings and foreign line measurements will also be recorded. • Collected data will be processed daily throughout the survey to verify accuracy and completeness. • Upon completion of all surveys, LSC will demobilize from the project site. Office support will be provided by a project manager, engineering personnel, and data technicians as required to efficiently execute the project, process the data, and generate LSC's final report. LSC's final report will describe the survey completed, obstacles encountered, skipped sections, problem areas/troubleshooting encountered, present the findings, and provide recommendations, if applicable. Included within the final report will be the following: • Data deliverables. o Waveprints. o Post -processed data. ■ Raw files in .csv and .svy format. ■ Processed data in Excel format. o Two-line CIS graphs. • Daily reports. • Equipment calibration certificates. • Personnel and operator qualifications. DELIVERABLES 1 Daily Documentation 2 Final Report ASSUMPTIONS AND EXCEPTIONS SCHEDULE Daily while onsite Within 45 days of field work completion 1. Delays or standby time caused by factors outside the control of LSC will be billed on a time and materials basis per the rate sheet. 2. Hutchinson will set interruption and coordinate foreign interruption, if applicable. 3. A field crew of three or two personnel may be utilized, as cost impacts are assumed to be negligent in either staffing scenario. 4. Paved crossings will be skipped, and drilling will not be required. 5. Hazardous crossings which could compromise crew safety or damage equipment will be skipped. 6. The right-of-way is brushed and accessible. Dense brush areas will either be skipped or offset surveyed depending on pipe depth and crossing conditions. 7. LSC takes no exceptions to this project. Project # 76925250617 2025 Close Interval Survey Page 2 TERMS AND CONDITIONS This proposal, and in particular the pricing contained herein, is subject to the parties reaching mutually agreeable terms of a contract or purchase order. STATEMENT OF FEES Our best estimate for the overall cost of this project, on a time and materials basis, is $30,419. Table 1: Statement of Fees # Description Rate Unit Qty Total 1 Table A.1: Survey $27,580.00 Each 1 $27,580.00 2 Table A.2: Data Management and Reporting $2,839.00 Each 1 $2,839.00 Total $30,419.00 Approved By any �2z�z� Date April 16, 2025 Project # 76925250617 2025 Close Interval Survey Page 3 APPENDIX 1 - DETAILED COST ESTIMATE Table A. 1: Su # Description Rate Unit Qty Total 1 CP Technician II, AMPP Certified $135.00 Hour 80 $10,800.00 2 CP Technician $90.00 Hour 84 $7,560.00 3 CIS Equipment Package $370.00 Hour 8 $2,960.00 4 Per Diem $195.00 Day 16 $3,120.00 5 4x4 Vehicle (x2) $135.00 Day 16 $2,160.00 6 Mileage (IRS Published Rate) $0.70 Mile 1400 $980.00 Total $27,580.00 Table A.2: Data Management and Reporting # Description Rate Unit Qty Total 1 Data Technician $98.00 Hour 8 $784.00 2 Engineer $150.00 Hour 10 $1,500.00 3 Project Manager $185.00 Hour 3 $555.00 Total $2,839.00 Project # 76925250617 2025 Close Interval Survey Page 4 CLIENT INFORMATION DATE: 6/4/2025 COMPANY: Hutchinson Utilities REPRESENTATIVE: Byron Bettenhausen EMAIL: Bbettenhausen@hutchinsommn.gov PROPOSAL #: 25-393P Project Name: 20 Mile Close Interval Survey Project Locations: Trimont, MN 43.758413,-94.750431 to 44.008326,-94.637985 SCOPE OF WORK Close interval survey (CIS) 20 miles of pipeline • Hutchinson MN Utilities to notify surrounding landowners of the CIS • Mobilize to project location • Set all rectifiers to interrupt on a 3 second ON and 1 second OFF starting in the OFF position • Verify interruption daily • Hutchinson MN Utilities to notify any foreign operators of the planned CIS and request interruption on the same cycle • Perform CIS/DOC over the line • Wire to be removed daily • Provide final report at the conclusion of the project to include survey data, waveforms, graphical plots, and summary SUBMITTALS • Final report CLIENT TO PROVIDE • Access to site • ROW and environmental review and approval • All permitting (state, local, and internal) • Existing CP records and drawings • Landowner notification ITEMS NOT INCLUDED • Troubleshooting and/or repair of the CP system SCHEDULE • Work will be scheduled upon receipt of signed proposal and work order • Estimated duration is (5) days plus reporting time; final report package to be provided within 30 days of project completion BLUE SKY DATA OVERLAY/COMPARISON $4,600.00 20 MILE CIS ON MAINLINE $34,990.00 TOTAL LUMP SUM PROPOSAL $39,590.00 TERMS & CONDITIONS • Tariff Adjustment Clause: The prices quoted herein are based on current tariffs and duties. In the event of any changes in tariffs, duties, or other governmental charges imposed on the goods and services quoted, we reserve the right to adjust the prices accordingly • Mobilization is quoted using travel rates with 7 days advanced notice - failure to provide the minimum advance notice specified in this section may result in additional charges • Payment terms are Net 30 days from the date of NIS invoice • No provisions have been made for retention in this proposal • Any change in the scope of work as detailed in this proposal, will allow NIS to revise its quotation • Any changes to the contracted scope of work shall be reported to NIS management prior to the start of the work • NIS overtime rates apply after eight (8) hours in a day and for all hours worked on Saturday, Sunday or statutory holiday • Standby hours for labor and equipment will be charged for a minimum of eight (8) hours per shift, per day, per Time and Material rate sheet • Shut down with less than 72-hour notice will result in twenty-four (24) hours billing for all personnel and equipment on site • Shutdown due to inclement weather may be billed at eight (8) hours plus per diem each day • Daily travel time is charged portal to portal at the applicable rate at the time the travel occurs • Site specific orientation, testing and/or examination at the direction of the client or the facility owner, will be charged at the applicable labor rate. Fees for training will be billed at cost • Progress invoices may be issued to assist Client in cost tracking for this project • Should NIS be required to provide any item not specified in the sections "Scope of Work," additional charges shall apply • All NIS Terms and Conditions will apply unless otherwise stated herein • NIS personnel reserve the right not to work in any areas or conditions deemed unsafe Thank you, NIS Representative Date Client Representative Date THIS PROPOSAL EXPIRES ON: 7/19/2025 2 of 2 HUTCHINSON UTILITIES COMMISSION ^I'�xP61Tti'°" Board Action Form Agenda Item: Approve Req# 10278 - Generator #1 Transformer Radiator Repair Presenter: Dave Agenda Item Type: Time Requested (Minutes): 5 New Business Attachments: Yes BACKGROUND/EXPLANATION OFAGENDA ITEM: The step up transformer for Unit #1 has 9 radiators that are rusting and need to be sandblasted and painted to avoid a potential leak. Global Transformer Solutions has provided a quote for $66,215.00 to complete the repairs. The work will take two weeks to complete and will need to be coordinated with the repair facility sometime this fall. We received a no quote from REVOLT electrical services since they would be subcontracting the work to Global Transformer Solutions. BOARD ACTION REQUESTED: Approve Req# 10278 Fiscal Impact: 66, 215.00 Included in current budget: Yes Budget Change: No PROJECT SECTION: Total Project Cost: Remaining Cost: W' HUTCHINSON UTILITIES PURCHASE REQUISITION HUTCHINSON UTILITIES COMMISSION 225 MICHIGAN ST SE HUTCHINSON, MN 55350 Phone:320-587-4746 Fax:320-587-4721 GLOBAL TRANSFORMER SOLUTIONS CORP. 2220 COUNTY RD 210 W, STE 108 JACKSONVILLE, FL 32259 Note Description: Unit #1 Transformer Radiator Repair Date Requisition No. 06/17/2025 010278 Required by: Requested by: dhunstad Item No. part No. Description Qty Unit Due Date Unit Price Ext. Amount PAUWELS #9245211 RADIATOR REPAIR - MFG. PART: 1 1.00 EA $66,215.000 $66,215.00 Total: 66, 215.00 Date Printed: 06/17/2025 Requisitioned By: dhunstad Page: 1/1 May 11, 2025. Dave Hunstad Electric Transmission/Distribution Manager Hutchinson Utilities Commission 320-583-9330 �.v I Quote44202713Revl .0 Subject: Hutchinson Utilities-Pauwels#9245211-Radiator Repair Mr. Hunstad, Global Transformer Solutions Corp. is pleased to provide a proposal to perform the radiator repair and testing of Pauwels49245211 transformer located in the city of Hutchinson, WI. The following is the proposed scope of work. Transformer Radiator Painting & Installation ➢ Two mobilization /de -mobilization to the jobsite (Hutchinson, MN.) ➢ Supply a crew of 4 qualified transformer technicians for two days onsite each trip. ➢ Supply and build three pallets to properly contain all 9 radiators. ➢ Close all 18 radiator valves. Remove staves and fans. ➢ Set up proper containment, 1/z micron filter cart, and oil hoses. ➢ Drain all 9 radiator banks into clean dry storage totes while radiators are painted. ➢ Supply 36 steel blanking radiator blanking plates, gaskets for shipping and storage. ➢ Customer to supply boom truck and operator to assist in radiator removal. ➢ Remove radiators, install blanking plates, Install stiffeners between radiators for shipping and band properly to pallet for shipping. ➢ Customer to supply forklift and operator to load three pallets per scheduled pick up and unload upon their return (estimated 2-week turnaround). ➢ 9 radiators to be sandblasted and painted Ansi 70 light gray at factory and returned. ➢ Return to site to install the 9 radiators, and fans previously removed. ➢ Supply 18 new rad gaskets, lubricate, torque to specifications. ➢ Customer to supply boom truck and operator to assist in radiator assembly. ➢ Filter press oil back into the top of the transformer utilizing 1/z micron filter press. Purge all radiators, conservator. And Buchholtz relay. Restore all valves to the in- service state. 1 ➢ Furnish a formal written field with any of our comments, recommendations, and field pictures taken at the time of service. For this service we propose a fixed price cost of $66,215.00. Clarifications and conditions to the proposal We have assumed weekday working hours, Monday through Sunday, and do not include any holidays. All taxes, if applicable, would be in addition to the quoted prices. The quote is valid for 30 days. An invoice will be sent at the conclusion of the fieldwork and is due Net 15. The customer is responsible for de -energizing the equipment which shall include switching, grounding, lock -out / tag -out and isolating all cable terminations from the transformer. Delays not caused by GTS will be billed and submitted at our T&M rates. The warranty for the project is 12 months from the completion date in the field and covers the work performed by GTS. The quote is only valid for transformers with oil less than two PPM PCBs (Test date must be within six months of project date). Please feel free to call me at any time with your comments, questions, or other requests at (612) 710-6088. We look forward to working for you. Sincerely, Brett Ptacek Director of Operations Global Transformer Solutions Corp. 1584 Reidner LN Centuria WI, 54824 612-710-6088 cellular 2 I