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10-29-2025 HUCCP
HUTCHINSON UTILITIES COMMISSION AGENDA REGULAR MEETING October 29, 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. Natural Gas Service Requirements & Charges ii. Temporary Service — Natural Gas iii. Natural Gas Meter Requirements & Placement iv. Meter Testing — Natural Gas v. Natural Gas Service Work vi. Locating Customer's Underground Utilities — Natural Gas b. Approve Changes 7. UNFINISHED BUSINESS 8. NEW BUSINESS a. Approve 2025 Audit Services with Conway Deuth & Schmiesing b. Approve Req#010415 — B-MN Data Centers Materials C. Approve setting a Special Budget Workshop meeting d. Approve Rescheduling the December 31, 2025 Regular Commission Meeting if needed e. Discussion and Approval on the level of Carbon Free/Renewable Power Supply Mix 9. ADJOURN MINUTES Regular Meeting — Hutchinson Utilities Commission Wednesday, September 24, 2025 Call to order — 3:00 p.m. President Matt Cheney called the meeting to order. Members present: President Matt Cheney; Secretary Don Martinez; Vice President Troy Pullis; Commissioner Kathy Silvernale; Commissioner Tom Lambert; GM Jeremy Carter; Attorney Marc Sebora: 1. Conflict of Interest 2. Approve Consent Agenda a. Approve Minutes b. Ratify Payment of Bills Motion by Commissioner Martinez second by Commissioner Lambert to Approve the Consent Agenda. Motion carried unanimously. 3. Approve Financial Statements Mr. Martig presented the Financial Statements. Electric Division net loss increased by $76k over August 2024. Usage was down 6.84% in part due to timing difference in August billing days year over year for the industrial customer. Sales for Resales were up $726k due to a large increase in generation sales into the market. Large generation is also reason for the $230k increase in generator fuels and chemicals. Natural Gas Division is similar to past year. August Net Income decreased by $82k. Operating Expenses were up due to some regulatory and legal expenses as well as some reimbursable expenses for Fairfax and Heartland Corn. GM Carter noted the swing in the power cost adjustment year over year. All is tracking well on the Retail side. GM Carter also reviewed market sales, wholesale rates and time of use rates. Motion by Commissioner Silvernale, second by Commissioner Pullis to Approve the Financial Statements. Motion carried unanimously. 4. Open Forum 5. Communication a. City Administrator— Matthew Jaunich — i. Construction of the downtown apartment complex to start in October ii. Conditional Use Permit on Data Center was approved iii. Working with Dave on Solar for public buildings iv. Potentially 3-4 housing developments coming in next 1-2 years '7=big0"017 Dan Lang, Engineering Services Manager — 1. Construction at the Hutch Sub update ii. Dave Hunstad, Electric Transmission/Distribution Manager — Nothing to Report iii. Mike Gabrielson, Production Manager — Nothing to Report iv. Jared Martig, Financial Manager — Nothing to Report v. Byron Bettenhausen, Natural Gas Manager — 1. River Crossing Project is completed, thank you to Staff and residents. 2. DRS 3 completed 3. Final stretch of construction season c. Human Resources — Angie Radke - i. Will be meeting with Insurance Broker on PFML percentage rates ii. Benefits right around the corner, finalizing percentage increase iii. Open House Oct 7 from 4-7pm d. Legal — Marc Sebora — i. Nothing to report e. General Manager — Jeremy Carter i. Working on Cash Flow and what might push into 2026 ii. Natural Gas prepaid contracts update iii. Working on Budgets and CIP iv. New Ulm Contract Update v. Data Center update 6. Policies a. Review Policies i. Electric Service Requirements and Changes ii. Temporary Service iii. Temporary Service in Case of Underground Failure iv. Electric Meter Placement v. Sealing of Meters vi. Meter Testing vii. Right -of -Way Clearing viii. Tree Removal or Trimming ix. Locating Customer's Underground Utilities No changes recommended at this time b. Approve Changes i. Security Light Rental — Rate to Furnish and Maintain Fixture ii. Rate Schedule — Electric iii. Rate Schedule — Natural Gas Ms. Radke spoke of the policy changes to match what was approved by the City Council and Commission in 2023. GM Carter reviewed the last Cost of Service Study and how it relates to the Rate Schedule movements. GM Carter also noted that a new Cost of Service Study will need to be completed in 2027. 2 Motion by Commissioner Martinez, second by Commissioner Silvernale to Approve Policy Changes. Motion carried unanimously. 7. Unfinished Business 8. New Business a. Approve Amendment to HCP's Firm Transportation Agreement GM Carter presented Approval of Amendment to HCP's Firm Transportation Agreement. HUC entered into a Natural Gas Firm Transportation Capacity Agreement with Heartland Corn Products (HCP) on November 1, 2023 to provide firm transportation capacity in the amount of 12,300 Dth/day. Along with the Firm Transportation Agreement, HCP also entered into a Firm Capacity Reservation Agreement on December 20, 2023 to earmark an additional 4,700 Dth/day of capacity to account for future growth and natural gas needs in the operations of HCP. At this time, HCP is requesting to convert 400 Dth/day from the reservation agreement to the firm transportation agreement in addition to extending the reservation agreement an additional 2 years. The amendment will bring the firm transportation agreement to 12,700 Dth/day of firm capacity on the pipeline. Motion by Commissioner Pullis, second by Commissioner Lambert to Approve Amendment to HCP's Firm Transportation Agreement. Motion carried unanimously. b. Approve Amendment to HCP's Reservation Agreement GM Carter presented Approval of Amendment to HCP's Reservation Agreement. At this time, HCP is requesting to convert 400 Dth/day from the reservation agreement to the firm transportation agreement in addition to extending the reservation agreement an additional 2 years. The amendment will bring the reservation agreement down from 4,700 Dth/day to 4,300 Dth/day. Motion by Commissioner Silvernale, second by Commissioner Martinez to Approve Amendment to HCP's Reservation Agreement. Motion carried unanimously. c. Approve Memorandum of Agreement Relative to PFML Ms. Radke presented Approval of Memorandum of Agreement Relative to PFML. HUC agreement for IBEW #949 dated January 1, 2024-December 31,2026 had a provision to Article XX — Health and Disability Insurance to have both parties agree to a re -opener on or before June 1, 2025, to meet and negotiate specifically regarding contributions toward the Paid Family Medical Leave (PFML) premium. Since that time, both parties agreed effective January 1, 2026, the employer and employee will split the premiums for the Minnesota PFML or alternative private plan 3 on a 50/50 basis, with the employee share payable through payroll deductions pursuant to Minn. Stat. 268B.14. Employees may utilize accrued paid sick leave to supplement PFML not to exceed 100% of the regular wage of the employee. In the event sick leave is exhausted, employees may utilize other accrued paid leave to supplement PFML not to exceed 100% of the regular wage of the employee. Motion by Commissioner Martinez, second by Commissioner Pullis to Approve Memorandum of Agreement Relative to PFML. Motion carried unanimously. d. Approve Large Power Customer Tariff GM Carter presented Approval of Power Purchase Agreement and Credit & Security Agreement. Staff is requesting the Board to consider adding a Large Power Customer Tariff to HUC's current rate classes. The new classification would allow future high load interruptible customers the ability to entertain services from HUC under the classification provided the requirements are met. GM Carter reviewed the factors that differentiate the Large Power Tariff from other rate classes, which include; Load Factor must be a minimum of 90%, Electric service must be interruptible, Minimum load must be 5 MW's, Customer must enter into a Power Purchase Agreement with HUC, Customers will be expected to cover upfront costs of infrastructure needed to service the load and, Customers will be expected to enter into a security & collateral agreement to limit HUC's exposure to the power supply costs. Discussion was held on types of business that would fall into this class and if changes to the rates can be made. Motion by Commissioner Pullis, second by Commissioner Silvernale to Approve Large Power Customer Tariff. Motion carried unanimously. e. Approve Power Purchase Agreement and Credit & Security Agreement GM Carter presented Approval of Power Purchase Agreement and Credit & Security Agreement. Upon approval of the agreements, the customer will be finalizing the purchase of the land and site plans with the City of Hutchinson. HUC and the customer will finalize the specifications and ordering of the equipment needed to service the future load. It is anticipated the load will come on line in the later half of 2026 barring any set backs on constructing the building and receiving the necessary equipment. GM Carter highlighted the articles in the Power Purchase Agreement. The term of the Power Purchase Agreement is a 5-year commitment. GM Carter also reviewed the Credit & Security Agreement, which is a stand-alone agreement from the Power Purchase Agreement. Discussion was held on the agreements and the provisions that are in the 12 agreements. Motion by Commissioner Pullis, second by Commissioner Lambert to Approve Power Purchase Agreement and Credit & Security Agreement. Motion carried unanimously. 9. Adjourn There being no further business, a motion by Commissioner Lambert, second by Commissioner Pullis to adjourn the meeting at 3:44pm. Motion carried unanimously. 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(0 °a w u u u Q w x x a zH- U u7 l.0 f` Cl M J' l.0 f`� Cl N M J' Cl Cl Cl H H H H H N N N N M M M M M M M M M M M M Ln z z z z z z z z z z z z .. � � C7 C7 C7 C7 C7 C7 C7 C7 C7 C7 C7 C7 oo b O O -li u) a) N(o ,5.,' (0 C7 N N N N N N N N N N N N O X 0 Q O O O O O O O O O O O O N f7 J-) N N N N N N N N N N N N N M •• x un un un un un un un un un un un un CD U) r1 '.D Q U Cia O r1 O r1 O r1 O r1 O r1 O r1 O r1 O r1 O r1 O r1 O r1 O r1 +-) i O H un N O O un H oo M M Ln 3' CSl 3' un OJ oo N 3' f� Ln O l0 f� H O O O O O O O O O O O O O O O O O O N l0 N l0 0 r O l0 3' O O oc)r l0 r oc*)l0 O Ln* O Ln* O Ln* Ln* un NC; h oc)M CD CD O un l0 N un l0 N Ln H h H Ln H l0 H h N O O N N H O N O H H N H (\j N H M h OJ l L l N OJ Ln N H O H H H a) a Q o O oc) O Ln O 31 O 31 O oc) O 31 O 31 O oc) O oc) O O O O Ln O Ln O Ln O o O o O 31 O a-1 I I I I I I I I I I I I I I I I I I I O M in h h N CSl CSl N N CSl CSl H in in in O O h 0 O 61 Oo Oo Oo 61 OJ OJ 61 61 m m H m m m O O OJ u O O O O O O O O O O O H O O O un un O U1 H W �D U W N w �D w �D �D �D a s �D H H Z Ga Ga Cia Cia H �a H �a Cia H Ln N crz a 1 H a O a O crz crz a O a O a O O N Q C7 W U1 m W Cia Q W U1 FC 0 Cia H H Cia m a) m a) m a) Cia M M Cia \ O 60 z W U H a a H I (�(', (�(', U H U H U H N oo a x a H O H O —1 ro H O W w W w H O H O a Q s Q H O Z\ H OH W W W U1 H Q Hrl a f-I H a 0 s 0 H a) U1 a) U1 a) U1 H � x � x H U 1 N a '11 w Q M l0 w H H� f0 M l0 w w H U U a) a) a) M O O M l0 .�- U1 H M F4 X Mu CJ M ,'� ,'� a rl ri rl M F4 F4 M n '11 0 ,H �D U) a w U) H oo D4 D4 oo H H oo a w s w H v) -P v) -P v) -P oo a W s W oo o Z a N w +- p, z H Q �D o v) H v H z w �D U� U� a1 z W ,'� a w ,'� a w z w m m a�5 W O �5 O �5 D z w x x z w O\ �7 w N m H a \ n w S4 Sa a x U H U H U U U1 U1 U U1 U1 a a a) U x x H U a w z +) +) w w x w w H H w w w w p o a ro Q w x � Q H a rt rt x U w o w x U w a w s x U � O � O U x .H a .H a .H a x U a w x U w x Q a p o a z w H a W � w H C u w N U1 Q o O z a a o H rz H O O U i) G] H ' H H Q u H 04 L1a U1 x a a o z a U H U H U1 x U Q u a a o oQ D4 w w a w U H z a n O H H z w q H Q w (0 Q o a z z O a a a a a U u7 0) O H M J' u7 I— 61 N N M M M M M M M M oo M oo M oo M oo M oo M oo M oo Mu oo M oo Ln oo b 0 O -li (r) a) Ln � 1 N(o ,5.,' +-) (0 C7 Ln N Ln N Ln N Ln N Ln N Ln N Ln N Ln N Ln N O X U Q O O O O O O O O O N f7 -P N N N N N N N N N N M •• x U Ln Ln Ln Ln Ln Ln Ln Ln Ln N f-I I - a)•• � \ \ \ \ \ \ \ \ \ CD Ul Q r1 '.D Q -(', U �5 Cia O r1 O r1 O r1 O r1 O r1 O r1 O r1 O r1 O r1 O 0 H OJ H N a w H E� H a Ln H N D Fo � N z\ O c N z\ H � U �D Ln O o z +) a N w a O\(J .H w rn �4 F U \ � cn a ro q a O a z w w w w � 0 q a z x m u w Q U .4 U w x u (0 a ZH- 14 U N u -) Ln oo b O O -li (r) Ln � 1 +-) O O Q N f7 J-) x U \ N •• O � Q U O N N H O 3' 3' O O 3' 3' in 61 M H H 61 in 31 31 O L o 31 QQ 00 00 O O O O O I I I I h h O N M M O 6 6 6 I I I I I O O O O O N I Ln Q Ln Sa z \ O q Ln J-) w (0x U a W w .11 O q H w cn w \ cn 0 o a a w H q x CW-i N W N I H M W H oo u a w z 0 > w s-1 H C H w x w C7 W H H S H U a a a w w U u � H z w u H a Z w u Q w z U H w w a o 0 0 W W H z � H O fx H cn E� E� H W Q � � a a a w w a z O O H U q q U Q Q w w o �D �D N N q q N Ci J' l.0 U U OD w w OD w OD oo w G7 G7 U U W W W W co co C7 C7 C7 C7 E-i E-i U U H H Ln Ln Ln Ln C7 N N N N z z N O N O N O N O N H H Ln Ln Ln Ln O O O O w H H H H HUTCHINSON UTILITIES COMMISSION COMBINED DIVISIONS FINANCIAL REPORT FOR SEPTEMBER, 2025 Combined Division Customer Revenue Sales for Resale NG Transportation Electric Division Transfer Other Revenues Interest Income TOTAL REVENUES Salaries & Benefits Purchased Commodities Transmission Generator Fuel/Chem. Depreciation Transfers (Elect./City) Operating Expense Debt Interest TOTAL EXPENSES NET PROFIT/(LOSS) 75% of Year Comp. 2025 2024 Di . %Chna 2025 2024 Di %Chna Full Yr Bud %of Bud $ 2,609,667 $ 2,552,010 $ 57,657 $ 684,339 $ 389,707 $ 294,632 $ 180,360 $ 185,172 $ (4,812) $ 60,639 $ 60,383 $ 255 $ 105,999 $ 74,260 $ 31,739 $ 77,832 $ 79,910 $ (2,078) $ 3,718,836 $ 3,341,442 $ 377,394 $ 609,438 $ 622,691 $ (13,253) $ 1,318,810 $ 1,139,372 $ 179,438 $ 304,106 $ 252,868 $ 51,237 $ 225,773 $ 141,288 $ 84,486 $ 345,710 $ 368,577 $ (22,867) $ 222,524 $ 222,269 $ 255 $ 188,373 $ 322,838 $ (134,465) $ 49,688 $ 58,538 $ (8,850) $ 3,264,422 $ 3,128,441 $ 135,982 $ 454,414 $ 213,001 $ 241,413 2.3% $ 26,464,605 $ 26,272,411 $ 192,194 0.7% $ 38,041,145 69.6% 75.6% $ 5,919,324 $ 2,699,211 $ 3,220,113 119.3% $ 3,490,250 169.6% (2.6%) $ 1,558,721 $ 1,464,706 $ 94,015 6.4% $ 2,071,218 75.3% 0.4% $ 545,750 $ 543,450 $ 2,300 0.4% $ 727,666 75.0% 42.7% $ 534,336 $ 1,203,620 $ (669,284) (55.6%) $ 483,841 110.4% (2.6%) $ 595,349 $ 758,760 $ (163,411) (21.5%) $ 633,457 94.0% 11.3% $ 35,618,084 $ 32,942,157 $ 2,675,927 8.1% $ 45,447,577 78.4% (2.13%) $ 5,820,412 $ 5,873,622 $ (53,210) 15.7% $ 14,864,766 $ 14,207,502 $ 657,264 20.3% $ 2,113,148 $ 1,993,328 $ 119,820 59.8% $ 1,990,259 $ 1,036,629 $ 953,630 (6.2%) $ 3,132,624 $ 3,288,755 $ (156,132) 0.1% $ 2,002,719 $ 2,000,421 $ 2,298 (41.7%) $ 2,680,595 $ 2,474,740 $ 205,856 (15.1%) $ 447,192 $ 526,942 $ (79,750) 4.3% $ 33,051,714 $ 31,401,939 $ 1,649,775 113.3%1 2,566,370 $ 1,540,218 $ 1,026,152 September September i, YTD YTD 2025 2024 Change 2025 2024 Change Gross Margin %: 36.8% 39.9% -3.1% 34.1% 33.0% 1.0% Operating Income Per Revenue $ (%): 9.6% 4.2% 5.3% 5.9% 0.8% 5.1% Net Income Per Revenue $ (%): 12.2% 6.4% 5.8% 7.2% 4.7% 2.5% (0.9%) $ 8,248,534 70.6% 4.6% $ 20,256,167 73.4% 6.0% $ 3,015,064 70.1% 92.0% $ 1,284,200 155.0% (4.7%) $ 4,310,000 72.7% 0.1% $ 2,670,292 75.0% 8.3% $ 3,174,901 84.4% i5.1% $ 596,257 75.0% 5.3% $ 43,555,415 75.9% $ 1,892,162 135.6% 2025 HUC Budget Target 34.2% 3.5%N 4.2%N uuIIUuIINNI HUTCHINSON UTILITIES COMMISSION ELECTRIC DIVISION FINANCIAL REPORT FOR SEPTEMBER, 2025 2025 2024 Di . Electric Division Customer Revenue $ 2,043,346 $ 2,054,926 $ (11,580) Sales for Resale $ 684,339 $ 389,707 $ 294,632 Other Revenues $ 43,964 $ 43,788 $ 176 Interest Income $ 40,310 $ 41,349 $ (1,039) TOTAL REVENUES $ 2,811,959 $ 2,529,770 $ 282,189 Salaries & Benefits $ 449,948 $ 477,578 $ (27,630) Purchased Power $ 1,006,736 $ 870,143 $ 136,593 Transmission $ 304,106 $ 252,868 $ 51,237 Generator Fuel/Chem. $ 225,773 $ 141,288 $ 84,486 Depreciation $ 248,096 $ 275,821 $ (27,725) Transfers (Elect./City) $ 172,789 $ 172,534 $ 255 Operating Expense $ 135,915 $ 254,070 $ (118,154) Debt Interest $ 32,771 $ 35,305 $ (2,533) TOTAL EXPENSES $ 2,576,134 $ 2,479,605 $ 96,529 NET PROFIT/(LOSS) $ 235,825 $ 50,165 $ 185,660 75% of Year Comp. %Chna 2025 2024 Di %Chna FullYrBud %of Bud (0.6%) $ 18,149,164 $ 18,293,830 $ (144,666) (0.8%) $ 25,609,217 70.9% 75.6% $ 5,919,324 $ 2,699,211 $ 3,220,113 119.3% $ 3,490,250 169.6% 0.4% $ 251,990 $ 191,083 $ 60,907 31.9% $ 191,126 131.8% (2.5%) $ 315,194 $ 391,927 $ (76,733) (19.6%) $ 333,457 94.5% 11.2% $ 24,635,673 $ 21,576,051 $ 3,059,622 14.2% $ 29,624,050 83.2% (5.8%) $ 4,360,494 $ 4,371,912 $ (11,418) 15.7% $ 9,659,629 $ 9,081,191 $ 578,438 20.3% $ 2,113,148 $ 1,993,328 $ 119,820 59.8% $ 1,990,259 $ 1,036,629 $ 953,630 (10.1%) $ 2,253,054 $ 2,451,459 $ (198,404) 0.1% $ 1,555,101 $ 1,552,802 $ 2,299 (46.5%) $ 1,821,040 $ 1,711,353 $ 109,688 (7.2%) $ 294,942 $ 317,742 $ (22,800) 3.9% $ 24,047,668 $ 22,516,416 $ 1,531,252 370.1% $ 588,005 $ (940,365) $ 1,528,370 (0.3%) $ 5,955,489 73.2% 6.4% $ 12,605,893 76.6% 6.0% $ 3,015,064 70.1% 92.0% $ 1,284,200 155.0% (8.1%) $ 3,200,000 70.4% 0.1% $ 2,073,468 75.0% 6.4% $ 2,145,148 84.9% 7.2% $ 393,257 75.0% 6.8% $ 30,672,519 78.4% 162.5%) $ (1,048,469) (56.1%) 75% of Year Comp. 2025 2024 Di . %Chna 2025 2024 Di %Chna FullYrBud %of Bud Electric Division Residential 4,533,699 4,646,581 (112,882) (2.43%) 41,980,430 40,231,610 1,748,820 4.35% 53,837,879 78.0% All Electric 121,380 120,560 820 0.68% 1,811,567 1,600,691 210,876 13.17% 2,462,216 73.6% Small General 1,437,107 1,501,862 (64,755) (4.31%) 13,701,847 13,104,100 597,747 4.56% 18,074,963 75.8% Large General 8,738,560 6,963,720 1,774,840 25.49% 70,192,990 59,136,653 11,056,337 18.70% 80,805,047 86.9% Industrial 8,332,000 8,544,000 (212,000) (2.48%) 75,075,000 84,231,000 (9,156,000) (10.87%) 110,542,769 67.9% Total KWH Sold 23,162,746 21,776,723 1,386,023 6.36% 202,761,834 198,304,054 4,457,780 2.25%1 265,722,875 76.3% September September YTD YTD 2025 HUC 2025 2024 Change 2025 2024 Change Budget Target Gross Margin %: 30.2% 33.6% -3.4% 28.2% 26.7% 1.6% 27.0% Operating Income Per Revenue $ (%): 7.3% 0.6% 6.7% 1.8% -5.2% 7.0% -3.5% Net Income Per Revenue $ (%): 8.4% 2.0% 6.4% 2.4% -4.4% 6.7% -3.5% Customer Revenue per KWH: $0.0882 $0.0944 -$0.0061 $0.0895 $0.0923 -$0.0027 $0.0964 $0.0964 Total Power Supply Exp. per KWH: $0.0826 $0.0750 $0.0077 $0.0856 $0.0780 $0.0076 $0.0804 $0.0804 Net Profit increased by $185,660 over September 2024. Usage was up but customer revenue was down in large part due to the credits from the power cost adjustment. Sales for Resale continue to be high with increased market sales. Operating Expenses were down mostly due to a $125,000 payment to the city a year ago for the School Road sewer project. Sales for Resale of $684,339 consisted of $453,339 in market sales, $98,000 in capacity sales to Rice Lake, $70,000 in capacity sales to AEP, and $63,000 in capacity sales to Nextera. September 2024 Sales for Resale of $389,707 included $145,457 in market sales, $98,000 in capacity sales to Rice Lake and $146,250 in capacity sales to AEP. September 2023 Sales for Resale of $349,084 consisted of $104,834 in market sales, $98,000 in capacity sales to Rice Lake and $146,250 in capacity sales to AEP. Overall Purchased Power increased by $136,593. MRES purchases increased by $27,083 and market purchases/MISO costs increased by $109,510. The average cost of MISO power was $31.94/mwh (2,050 mwh's purchased), compared to $26.99/mwh (1,590 mwh's purchased) in September 2024. Power "Credit" Adjustment for September 2025 was $.00865/kwhr crediting customers $198,625 for the month and $384,054 YTD. There was no power cost adjustment for September 2024 leaving the total customers were charged at $556,670 YTD. 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 SEPTEMBER, 2025 75% of Year Comp. 2025 2024 2 %Chna 2025 2024 E %Chna Full Yr Bud % of Bud $ 566,321 $ 497,084 $ 69,237 13.9% $ 8,315,441 $ 7,978,581 $ 336,860 4.2% $ 12,431,928 66.9% $ 180,360 $ 185,172 $ (4,812) (2.6%) $ 1,558,721 $ 1,464,706 $ 94,015 6.4% $ 2,071,218 75.3% $ 60,639 $ 60,383 $ 255 0.4% $ 545,750 $ 543,450 $ 2,300 0.4% $ 727,666 75.0% $ 62,035 $ 30,472 $ 31,563 103.6% $ 282,346 $ 1,012,537 $ (730,191) (72.1%) $ 292,715 96.5% $ 37,522 $ 38,561 $ (1,039) (2.7%) $ 280,156 $ 366,834 $ (86,678) (23.6%) $ 300,000 93.4% $ 906,876 $ 811,671 $ 95,205 11.7% $ 10,982,412 $ 11,366,106 $ (383,695) (3.4%) $ 15,823,527 69.4% $ 159,490 $ 145,113 $ 14,376 9.9% $ 1,459,918 $ 1,501,710 $ (41,793) (2.8%) $ 2,293,045 63.7% $ 312,074 $ 269,229 $ 42,845 15.9% $ 5,205,137 $ 5,126,311 $ 78,825 1.5% $ 7,650,274 68.0% $ 52,458 $ 68,768 $ (16,310) (23.7%) $ 859,555 $ 763,387 $ 96,168 12.6% $ 1,029,753 83.5% $ 97,614 $ 92,756 $ 4,858 5.2% $ 879,569 $ 837,296 $ 42,273 5.0% $ 1,110,000 79.2% $ 49,735 $ 49,735 $ (0) (0.0%) $ 447,618 $ 447,619 $ (1) (0.0%) $ 596,824 75.0% $ 16,917 $ 23,233 $ (6,317) 0.0% $ 152,250 $ 209,200 $ (56,950) 27.2% $ 203,000 75.0% $ 688,288 $ 648,835 $ 39,453 6.1% $ 9,004,047 $ 8,885,524 $ 118,523 1.3% $ 12,882,896 69.9% $ 218,589 $ 162,836 $ 55,752 34.2%1 1,978,365 $ 2,480,583 $ (502,218) (20.2%) $ 2,940,631 67.3% 75% of Year Comp. 2025 2024 2 . %Chnq 2025 2024 p %Chnq Full Yr Bud % of Bud Gas Division Residential 7,054,374 6,097,991 956,383 15.68% 279,539,470 239,678,966 39,860,504 16.63% 435,250,000 64.2% Commercial 8,866,591 8,625,158 241,433 2.80% 217,104,261 187,525,206 29,579,055 15.77% 337,584,000 64.3% Industrial 49,268,819 42,616,948 6,651,871 15.61% 596,381,130 549,358,536 47,022,594 8.56% 895,764,000 66.6% Total CF Sold 65,189,784 57,340,097 7,849,687 13.69% 1,093,024,861 976,562,708 116,462,153 11.93% 1,668,598,000 65.5% September September YTD YTD 2025 2025 2024 Change 2025 2024 Change Budget Gross Margin %: 59.0% 60.6% -1.6% 47.5% 46.4% 1.1% 48.0% Operating Income Per Revenue $ (%): 17.3% 16.2% 1.1% 15.4% 13.5% 1.9% 17.0% Net Income Per Revenue $ (%): 24.1% 20.1% 4.0% 18.0% 21.8% -3.8% 18.6% Contracted Customer Rev. per CF: $0.0065 $0.0061 $0.0005 $0.0067 $0.0067 -$0.0001 $0.0061 Customer Revenue per CF: $0.0136 $0.0144 -$0.0008 $0.0086 $0.0099 -$0.0012 $0.0087 Total N.G. Supply Exp. per CF: $0.0051 $0.0051 ($0.0000) $0.0050 $0.0055 ($0.0005) $0.0048 HUC Target $0.0087 $0.0048 Notes/Graphs: September Net Income increased by $55,752. Increased usage also led to an increase in purchased gas. Other revenues were higher due to reimbursements from Heartland Corn and Fairfax. September 2025 Fuel Credit Adjustment was $1.68441/MCF crediting customers $33,571 for the month and $660,334 YTD. Fuel Credit Adjustment for September 2024 was $1.19061/MCF crediting customers $21,357 for the month and $179,325 YTD. HUTCHINSON UTILITIES COMMISSION BALANCE SHEET - CONSOLIDATED SEPTEMBER 30, 2025 Electric Gas Total Total Net Change Division Division 2025 2024 Total (YTD) Current Assets UnrestrictedlUndesignated Cash Cash (2,878,510.78) 14,537,655.85 11,659,145.07 13,152,633.79 (1,493,488.72) 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 1,443,969.35 - 1,443,969.35 536,165.60 907,803.75 Rate Stabilization - Gas - 615,294.19 615,294.19 615,294.19 - Catastrophic Funds 800,000.00 200,000.00 1,000,000.00 1,000,000.00 - Restticted Cash Bond & Interest Payment 2017 789,818.75 - 789,818.75 986,380.20 (196,561.45) Bond & Interest Payment 2012 - 1,717,666.66 1,717,666.66 1,811,500.00 (93,833.34) 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 5,435,015.32 20,439,610.70 25,874,626.02 26,751,105.78 (876,479.76) Receivables Accounts (net of uncollectible allowances) 2,151,668.60 553,712.86 2,705,381.46 2,525,839.12 179,542.34 Interest 74,314.28 74,314.29 148,628.57 141,412.63 7,215.94 Total Receivables 2,225,982.88 628,027.15 2,854,010.03 2,667,251.75 186,758.28 Other Assets Inventory 2,188,809.94 522,257.70 2,711,067.64 2,557,484.89 153,582.75 Prepaid Expenses 427,554.11 28,393.86 455,947.97 353,015.20 102,932.77 Sales Tax Receivable 477,942.27 - 477,942.27 382,211.36 95,730.91 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 3,437,065.32 664,904.56 4,101,969.88 4,281,452.45 (179,482.57) Total Current Assets 11,098,063.52 21,732,542.41 32,830,605.93 33,699,809.98 (869,204.05) Capital Assets Land & Land Rights 690,368.40 3,899,918.60 4,590,287.00 4,590,287.00 - Depreciable Capital Assets 94,056,933.30 44,579,509.55 138,636,442.85 158,340,473.74 (19,704,030.89) Accumulated Depreciation (50,483,132.43) (23,132,670.83) (73,615,803.26) (94,935,700.81) 21,319,897.55 Construction - Work in Progress 5,538,784.84 204,109.78 5,742,894.62 6,186,267.48 (443,372.86) Total Net Capital Assets 49,802,954.11 25,550,867.10 75,353,821.21 74,181,327.41 1,172,493.80 Total Assets 60,901,017.63 47,283,409.51 108,184,427.14 107,881,137.39 303,289.75 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 SEPTEMBER 30, 2025 Electric Gas Total Division Division 2025 790,000.00 19, 546.00 2,992,675.21 131, 085.44 85,032.92 4,018,339.57 11,750,000.00 407,059.68 1,832,248.00 39,880.00 569,807.22 208,347.54 1,294,449.00 16,101,791.44 1,980,000.00 185,608.32 487,364.27 67,666.68 32,115.76 2,752,755.03 2,080,000.00 30,934.35 610,749.00 13,293.00 169,522.80 37,374.19 431,483.00 3,373,356.34 2,770,000.00 185,608.32 19, 546.00 3,480,039.48 198,752.12 117,148.68 6,771,094.60 11,750,000.00 2,080,000.00 437,994.03 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 19,475,147.78 Total Net Change 2024 Total (YTD) 2, 655, 000.00 115, 000.00 185,608.32 - - 19,546.00 3,141,142.41 338,897.07 234,252.08 (35,499.96) 97,064.95 20,083.73 6,313,067.76 458,026.84 12,540,000.00 (790,000.00) 4,060,000.00 (1,980,000.00) 657,059.31 (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 23,248,617.68 (3,773,469.90) 40,780,886.62 41,157,298.14 81,938,184.76 78,319,451.95 3,618,732.81 40,780,886.62 41,157,298.14 81,938,184.76 78,319,451.95 3,618,732.81 Total Liabilities and Net Position 60,901,017.63 47,283,409.51 108,184,427.14 107,881,137.39 303,289.75 Hutchinson Utilities Commission Cash -Designations Report, Combined 9/30/2025 Financial Institution Current Interest Rate Annual Interest Balance, September 2025 Balance, August 2025 Change in Cash/Reserve Position Savings, Checking, Investments varies varies varies 25,874,626.02 25,442,226.91 432,399.11 Total Operating Funds 25,874,626.02 25,442,226.91 432,399.11 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) 2,507,485.41 2,226,964.05 280,521.36 3,255,256.00 3,255,256.00 - 5,762,741.41 5,482,220.05 280,521.36 6,542,569.17 6,542,569.17 2,059,263.54 2,059,263.54 1, 942, 626.00 1, 942, 626.00 1, 000, 000.00 1, 000, 000.00 3,450,000.00 3,450,000.00 14,994,458.71 14,994,458.71 YE YE YE YE YTD HUC 2021 2022 2023 2024 2025 Target Debt to Asset 30.8% 31.4% 28.6% 26.0% 24.3% Current Ratio 5.22 4.47 4.48 3.67 3.94 RONA 0.41% -1.38% 1.96% 2.63% 2.70% Historical Change in Cash Balance Month End Electric Elec. Change Natural Gas Gas Change Total Total Change 9/30/2025 5,435,015 20,439,611 25,874,626 12/31/2024 6,134,710 (699,695) 17,717,453 2,722,157 23,852,164 2,022,462 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 9/30/2025 Change in Financial Annual Balance, Balance, Cash/Reserve Institution Current Interest Rate Interest September 2025 August 2025 Position �' Rr Savings, Checking, Investments varies varies varies 25,874,626.02 25,442,226.91 432,399.11 Total HUC Operating Funds 25,874,626.02 25,442,226.91 432,399.11 Debt Restricted Requirements Debt Restricted Requirements Total Restricted Funds Bond Covenants - sinking fund Bond Covenants -1 year Max. P & 1 789,818.75 1,183,256.00 1,973,074.75 691,214.06 98,604.69 1,183,256.00 - 1,874,470.06 98,604.69 Excess Reserves Less Restrictions, Electric 3,461,940.57 3,393,662.38 68,278.19 J11J! !!1 1 !1 J Operating Reserve Min 60 days of 2025 Operating Bud. 4,578,753.17 4,578,753.17 - Rate Stabalization Funds $400K-$1.2K 1,443,969.35 1,443,969.35 PILOT Funds Charter (Formula Only) 1,345,802.00 1,345,802.00 Catastrophic Funds Risk Mitigation Amount 800,000.00 800,000.00 Capital Reserves 5 Year CIP (2025-2029 Fleet & Infrastructure Maintenance) 2,750,000.00 2,750,000.00 Total Designated Funds 10,918,524.52 10,918,524.52 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% Current Ratio 5.70 4.96 4.35 2.38 2.19 3.75 RONA -1.2% -4.2% -0.9% -2.1% 1.1% NA �p, Hutchinson Utilities Commission Cash -Designations Report, Gas 9/30/2025 Change in Financial Annual Balance, Balance, Cash/Reserve Institution Current Interest Rate Interest September 2025 August 2025 Position F�' Rr Savings, Checking, Investments varies varies varies 25,874,626.02 25,442,226.91 432,399.11 Total HUC Operating Funds 25,874,626.02 25,442,226.91 432,399.11 Debt Restricted Requirements Bond Covenants - sinking fund 1,717,666.66 1,535,749.99 181,916.67 Debt Restricted Requirements Bond Covenants -1 year Max. P & 1 2,072,000.00 2,072,000.00 - Total Restricted Funds 3,789,666.66 3,607,749.99 181,916.67 Excess Reserves Less Restrictions, Gas 16,649,944.04 16,566,344.48 83,599.56 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% 13.0% 35%-50% Current Ratio 4.79 4.06 4.61 5.08 6.48 1.0-3.0 RONA 2.9% 3.0% 6.2% 9.1% 4.9% 2%-5% Notes/Graphs: ELECTRIC DIVISION Operating Revenue September 2025 CLASS AMOUNT KWH /KWH Street Lights 30,284.76 390 $77.6532 Electric Residential Service $481,963.99 4,533,699 $0.1063 All Electric Residential Service $14,326.28 121,380 $0.1180 Electric Small General Service $147,346.75 1,437,107 $0.1025 Electric Large General Service $736,641.72 8,738,560 $0.0843 Electric Large Industrial Service $632,782.94 8,332,000 $0.0759 Total $2,043,346.44 23,163,136 $0.0882 Power Adjustment ($0.00865) Rate Without Power Adjustment $0.09687 Electric Division Year -to -Date ® 2025 $ Amount ❑ 2024 $ Amount ® 2025 KWH110 ❑ 2024 KWH110 30,000,000 25,000,000 20,000,000 15,000,000 10,000,000 5,000,000 0 Residential All Elec. Resid. Small Gen. Srv. Large Gen. Srv. Large Industrial Sales For Resale Total NOTE: This graph includes sales for resale (capacity and energy sales) but excludes street lights and security lights NATURAL GAS DIVISION Operating Revenue September 2025 CLASS AMOUNT MCF /MCF Residential $137,299.38 7,054 $19.4630 Commercial $107,005.50 8,867 $12.0684 Large Industrial $27,137.72 4,045 $6.7093 Large Industrial Contracts $294,878.11 45,224 $6.5204 Total $566,320.71 65,190 $8.6873 Fuel Adjustment-$1.68000 Rate Without Fuel Adjustment $10.36726 Natural Gas Division Year -to -Date ❑ 2025 $ Amount ❑ 2024 $ Amount m 2025 MCF ❑ 2024 MCF 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 Large Industrial Total Contracts W Z E E W a` W N R D W 7 U R a 0 W 0 C e 7i U 0 0 0 o o U o N N N N N N O N N O N N N Q Q Q O O O O O O E _ N N N N N N Z Z Z N O O OM OM N C Z Z Z Z Z Z Z Z Z Z M 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 Z Z Z� Z Z Z O Z Z O Z Z Z N N N N N Q N N W M COO r W 0 M M rM O N 0 0 OW rO COO 0 0 r-00r-Lo V �M V r-Lo V COO OOO-O OW N�M OWLo V O V O�O0MM0NWIWMMrOO:OMN000M I CO �Mo�o r 00M IMS6N6-NOr�V�MMM- r�r�VM M-06WNu, - V oo oo �O� M OI� 1-M O0�� OLo WN CO OM rI� rI� V OM 0 r-N OCO OINN I� M oN V OON O.-�O0O.-O CO NO Oo LoWOM rN O cool OO VNCO NVO0) OoMi WOCO I�VMOOVCOMMMOMOVN�6�MOCOMO OO LVo rCO�MO1�V�L�o m00 0 OWCO O 0 WMV � OrW Mr N W Or0OO OM - M r � COM m� --CoW N 111- � OOOOri MCOOOW-WMMM MrM_ONMMMMWr V MNL6N V M MM NMI V L - L6 N L6 MM O O) MOOr V O -r�V M NV V V VM O)ON,6�c COV VMr�VM".r�C0 - C0 VMV V N O O O O O V W O V 0 0 0 0 0 0 0 V -000 00 oO CO 00 00 00 0 O O O O O N O O- M O O O O O O O n m 0 COM�M mmVooN�OOM 0 N MM NN NN�N� ,I - CO NN MOMCO N I��-N V I� N� M V NCO I�I� 06Ni" NCOm 6ri V HM O W CO COON NCOOD ON �0 rNV I� �M V M M00006� CON ISO M�- N 00000000000000000000 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O O O O O O O O O O O O O O O O O O 00�0000 �000� Hof �� � N6�1�00� ISO COO V V V M V V V V CO ENV V MN u%�-� M NN NN NN NN V M N OOO��V OOOOrM O co rO CO 0Co0 �00OMMMMO OW m COLO M �D V � CO�(D 6�M - - M6�CON MM CO MO(NN000M I�COO M I�O I� ��CONMM�N "tMM00MN�- V - - 0 co 0 0 M 0 N rMN V O�OM�MI�O� I�COOOMN01�M 0001��6�I�N I�I�I� �- r CO 0 0 0 0 0 0 0 0 0 0 0 0� 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0� 0 M V O ItCO O O N N CO LoO O NMrl- 0 CO 0 Lo COO 00o m It co OCON rl- LoOM00m M0 M V MI�nOOOm 60i OCOOCONO) V OcoM W W NCOO �000 W M MO B E M M 00060i � O V V OW-MMNM�CO CO CO OEM MI�OCO��MOM V OM O O� M V 0 OOi M M co�OOi Oo rM ONO co 0 V ',I- OOi 6riNn V m Obi 8M8MrON W W Cr 0 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 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 O O O O of O n� O O� cO O� O O O 000000 00� �00� nO O OOOO � O M V O M M � .0 .M MN CO S .0 O� .0 6 0� .O O� . - E V CO M .O . . . 0� 6 M. 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N ((O O) 00 O0 Ln N V O N -= N > (O O 00 (O N • O R (O O V V 00 00 O) (O rl N V o0 N 6% 0.: F N a s= rn J O a Q tlItlI V IIIIIIIIIIIIIIIIIIIIIIIIIIII u ° 0 O �N a` �Lri ~ U N -w > O N O O o 0 U C W L i LLJ O •CC� Q_ O C Q_ o 0 c� E cn c I cn E _/ D 0 =U a o c L L N m U E E d � 4+ _ 0 4-1 ^Q 0 �NW 0 F .� O Q 4 N W � +� U L N O o Z }� 0 0 0 m N C O 0 0 q k / k L L L Iq 0 04 CL 2 2 2 2 / o 0 C) / n m LO % 3 $ - k 2 / % o A � m / § =3 k k c f k � @ . 3 E 3 ¥ E / m k % % / \ / / k k kCL 0 m o w m E 2 m U E E / ƒ 2 § cc 2 2 / E A 2 � E g � % c @ a 2 k R / E 7 3 2 � cu _0 _0 \ / J k O £ k LL A k � J k O � / cu -T W � U) a O Q m L L L E O U) m i O O U) 3 cn 0 i O co O N 00 N N CO i U Q In N N U) O N O Ln � N Q O N In N O N C In N O N T LO Lp N O N in Q N Q O N i LO f6 N O N LO N N LL O N C LO N O N U V N N O N (O In V Cl) N U) Q U) T O LL E U) o O Cf w V N a LO N N CO O N O LO Z3 N Q O N LO N O N C LO N O N T LO (p N N In Q N Q O N i LO f6 N O N LO � N LL O N C LO N O N U y N 0 O N > O N z O N v U N O O N O 7 0 U N U) m cc U N c cl L 0 0 cu L 0 7 A a 0 N U) m cc U O a) O CM c cl L 0 0 cu L 0 7 us / cc/ g g \ k U) / / 0 $ � c 0 0 o U $ 7 CN CN U 2 c 0 @ D 3 % a $ / 0 E ƒ 2 m $ o / / 2 7 U & co e 3 ¢ m E 0 \ 2 k a q ƒ 0 / c C) / ƒ / q Work Order DesCriplim 12204 Cooling Tower Repairs 12402 Plant zCombustible Gas Detection System 12403 sxvOoComputer Upgrade us zzsnz Tuck Pointing Phase III zzsoz Rubber Roof Repair West Portion orPlant z 12503 Plant zPump Room Ventilation zzso« Plant zControl Panel Upgrade zzsos Unit zcozSystem Update Code Compliance 12506 Cooling Tower xeun:and Chem Injection zzsor Plant zNorth Ground Fans Electric Production Total Total Materials Labor Budgeted Actual Difference - - $ - 723,509.18 723,509.18 - - S - 40,875.05 $ 40,875.05 ym\000M - g 300,000o0 213.9e8A5 $ (86,001s5) 40,000o0 $ 40,000u0 103,506a1 *3,506.51 42.000.00 $ 42,000.00 $ (42,000.00) 30,000.00 s'000-on $ xs'000.00 ' $ (»s^oon.00) 80,000u0 20,000.00 $ 100,00000 $ (z»»»«».»») 20,000.00 $ 20,000.00 ' $ (20,000.00) 130,000.00 - g 130,000.00 - g (130,000.00) _'_50,000.00/ Work Order Descon 22301 Hutch Sub Transformer Upgrade Engineering 22401 Hutch Substation Transformer 22402 McLeod Sub Relay Replacement 22405 3M Sub SCADA Phase 2 22406 HTI Sub SCADA 22501 Pole Repair and Replacement 22502 Station Equipment 22503 Plant 1 Sub Circuit Breakers 22504 Plant 1 Sub Engineering for Willmar Line 22505 Right of Way Clearing 22506 Install Duct 22507 Ravenwood Circle 22508 Edmonton and Sherwood 22509 New Developments 22510 Ravenwood Circle 22511 Edmonton and Sherwood 22512 Transformer Replacements 22513 Transformer New Developments 22514 Meters 22515 Meter Testing Equipment 22516 Security Lights 22517 LED Street Light Conversion 22518 Reconductor Feeder 16 22519 Reconductor Feeder 16 Transformers 22520 Elk Ridge Development 22521 Elk Ridge Development Transformers 22522 Data Center Electric Distribution Total Total Materials Labor Budeted„ Actual Difference 2,740,692.50 2,740,692.50 829,812.43 829,812.43 150,000.00 150,000.00 9,552.50 (140,447.50) 878.35 878.35 - •- 139,578.78 139,578.78 15,000.00 - 15,000.00 - (15,000.00) 10,000.00 - 10,000.00 - (10,000.00) 110,000.00 - 110,000.00 - (110,000.00) 75,000.00 - 75,000.00 8,088.23 (66,911.77) - - - 3,360.44 3,360.44 18,000.00 65,000.00 83,000.00 51,821.65 (31,178.35) - - - 3,729.65 3,729.65 60,000.00 15,000.00 75,000.00 29,228.36 (45,771.64) - - - 3,269.24 3,269.24 - - - 1,160.28 1,160.28 50,000.00 15,000.00 65,000.00 2,512.58 (62,487.42) 60,000.00 15,000.00 75,000.00 745.52 (74,254.48) 36,000.00 - 36,000.00 57,060.00 21,060.00 30,000.00 - 30,000.00 - (30,000.00) - - - 831.81 831.81 175,000.00 35,000.00 210,000.00 19,123.50 (190,876.50) - - - 21,603.79 21,603.79 33,078.19 32,254.91 ® - - 14,099.68 14,099.68 $ 789,000.00 $ 145,000.00 $ 934,000.00 $ 4,002,482.39 3,068,482.39 Administrative Work Order Descri lion 52303 Replace 226 2012 Dodge RAM 1500 52501 Replace 451 Welding Truck 52502 Genie AWP 255 DC Manual Lift Total Total Budgeted Actual Difference 57,374.57 (57,374.57) 11,102.00 (11,102.00) $ - $ 68,476.57 $ 68,476.57 Natural Gas Work Total Total Order De" scri tion Materials Labor Budgeted Actual Difference 62501 Transmitter Calibration Equipment 8,500.00 - 8,500.00 1,822.66 (6,677.34) 62502 Misc Developments & System Improvements 25,000.00 5,000.00 30,000.00 25,204.99 (4,795.01) 62503 City Projects 7,000.00 2,000.00 9,000.00 22,497.88 13,497.88 62504 Improvements to Regulator Stations 20,000.00 3,500.00 23,500.00 283.02 (23,216.98) 62505 Service Lines 57,000.00 15,000.00 72,000.00 31,220.74 (40,779.26) 62506 Meters, AMI, and All Fittings 250,000.00 10,000.00 260,000.00 16,027.89 (243,972.11) 62507 Residential Regulators - _ - _ 62508 Industrial Metering and Regulation 25,000.00 3,500.00 28,500.00 490.90 (28,009.10) 62509 Edmonton Development - - - 1,127.31 1,127.31 62510 School Road River Crossing - - - 74,005.38 74 005.38 $ 392,500.00 $ 39,000.00 $ 431,500.00 $ 172,680.77 $ (258,819.23) HUTCHINSON UTILITIES COMMISSION 9 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. Natural Gas Service Requirements & Charges ii. Temporary Service — Natural Gas iii. Natural Gas Meter Requirements & Placement iv. Meter Testing — Natural Gas v. Natural Gas Service Work vi. Locating Customer's Underground Utilities — Natural Gas BOARD ACTION REQUESTED: None Fiscal Impact: Included in current budget: Budget Change: PROJECT SECTION: Total Project Cost: Remaining Cost: Natural Gas Service Requirements and Charges HUC shall not install any facilities until all affected properties are within 6 inches of final grade. HUC shall furnish and install the underground natural gas service line. The service line to the meter shall remain the property of HUC. Type/Size Fee Single-family residential — V IPS $600 — up to 150 ft. plus $4.00/ft. in excess of 150 ft. Multi-family/Commercial/Industrial — %" IPS $950 — up to 100 ft. plus $7.50/ft. in excess of 100 ft. Multi-family/Commercial/Industrial — 2" IPS $1900 — up to 100 ft. plus $9.00/ft. in excess of 100 ft. Industrial — 4" IPS and larger Time and Material Expense Service line length is defined as "distance from customer's property line to metering facilities", or in the instance the distribution main is located in rear easement, "distribution main to metering facilities". No structure or building may be located over natural gas lines or metering facilities. In the event that a structure or building is determined to be located over natural gas facilities, the natural gas facility must be relocated to a mutually agreed upon location. The customer shall be responsible for all costs associated with the relocation. No service line valve or any portion of the natural gas metering facilities may be buried. The customer shall be responsible for all costs incurred in raising all facilities. In the event owner requires relocation of the installed natural gas service line, Owner agrees to pay Hutchinson Utilities Commission the entire cost of relocating the service line as billed. Hutchinson Utilities Commission agrees to use its best efforts in repairing the premises in a workman -like manner and returning the premises to the same or similar condition as existed prior to establishing or repairing the underground service line. Hutchinson Utilities Commission shall begin installing excess flow valves, as of April 14, 2017, on all newly installed and replacement service lines serving the following types of services before the line is activated: A single service line to one single-family residence; A branched service line to a single-family residence installed concurrently with the primary single-family residence service line (i.e., a single EFV may be installed to protect both service lines); • A branched service line to a single-family residence installed off a previously installed single-family residence service line that does not contain an EFV; • Multifamily residences with known customer loads not exceeding 1,000 SCFH per service, at time of service installation based on installed meter capacity, and • A single, small commercial customer served by a single service line with a known customer load not exceeding 1,000 SCFH, at the time of meter installation, based on installed meter capacity. Hutchinson Utilities shall install either a manual service line shut-off valve or, if possible, based on sound engineering analysis and availability, an excess flow valve for any new or replaced service line with installed meter capacity exceeding 1,000 SCFH. All new natural gas consumer -owned fuel lines, downstream of the metering facilities, must be pressure tested, prior to the gas meter being set. The test must be verified by an approved inspector. Installation of Natural Gas Service Lines — November 1 through March 31 Final determination on installation of natural gas service lines during this time shall be made by HUC. Temporary Service HUC does not offer temporary natural gas service. Natural Gas Meter Requirements and Placement HUC shall furnish and install the natural gas meter at no charge to the customer. HUC reserves the right to specify the natural gas meter location on all installations. All meters must be located on an external wall of the building, at a horizontal distance of no less than 3 feet from fresh air intakes, windows or door openings. New construction natural gas meters must be located within 10 feet of the electric meter if HUC is providing both services. Access to all natural gas meters shall not be obstructed. Natural gas meters shall be located in ventilated spaces readily accessible for examination, reading, replacement or necessary maintenance. Decks, porches, etc. shall not be constructed over a natural gas meter. Natural gas meters shall not be located where they will be subject to damage, such as adjacent to a driveway or other locations subject to vehicular traffic, in public passages, where they will be subject to excessive corrosion or vibration or in areas subject to ice and snow damage. Natural gas meters shall not be installed directly beneath external stairways. Natural gas meters shall not be located where they will be subjected to extreme temperatures or sudden extreme temperature changes (e.g., air ducts, dryer vents). Manufacturer's installation specifications shall be adhered to when installing fresh air intake and exhaust terminations near natural gas metering facilities. Natural gas regulators shall be located - no less than 3 feet from any source of ignition or any source of heat that may damage the facilities. HUC requires a minimum of a 3-foot clear zone in front of the natural gas meter. Reasonable care must be taken to protect all metering facilities when remodeling, roofing, painting, etc. In the event of damage to the natural gas facilities, the customer shall be responsible for the cost of repairing or replacing the natural gas facilities. Conditions may exist which may require additional restrictions or distances (e.g. multiple meters, etc.). Please contact HUC if you should have any questions regarding your natural gas metering facilities. Modifications made to the customer's metering facilities, necessitated by customer changes, shall be performed by HUC, at the customer's expense. All natural gas service lines retired due to building demolition, overbuilding, etc. shall be retired at the customer's expense. HUC Natural Gas Division performs all retirement work on natural gas facilities. Estimate is provided by HUC Natural Gas Division when requested. All exceptions require the approval of HUC prior to the start of construction. if violations or deviations are determined, the customer shall be responsible for the cost of the correction. Single Family Dwellings HUC shall provide natural gas to residential customers at the standard delivery pressure of 7 inches of water column, measured at the inlet to the natural gas meter. All residential natural gas metering facilities shall be located on the side of the home within 6 feet of the front building wall. Front building wall is defined as the wall nearest the street of the resident's living space. Multi -Family Dwellings/Multiple Business Establishments Delivery pressures greater than 7 inches of water column, for multi -family and multiple business establishments, shall only be allowed by the prior approval of HUC. The customer must provide adequate over -pressure protection for all fuel lines subject to increased delivery pressure. The single metering of multiple -family dwellings, apartment buildings or multiple business establishments within a single building is permitted to the extent that each building is centrally heated. Individual metering is required for all individually heated, single-family private residences and each separately heated, owned and/or operated business. Please contact HUC for specifications regarding meter facilities. Commercial/Industrial Facilities Delivery pressures greater than 7 inches of water column, for commercial and industrial applications, shall only be allowed by the prior approval of HUC. The customer must provide adequate over -pressure protection for all fuel lines subject to increased delivery pressure. Please contact HUC for specifications regarding meter facilities. Meter Testing HUC shall periodically test all natural gas meters for accuracy and sound mechanical condition. Meters that have an average incest accuracy of 100, ± 2%, shall be considered accurate. Average accuracy is defined as the average of the open and check flow accuracies. Accounts for which the natural gas meter tests in excess of 102% are subject to a refund. This refund shall be based on the "as found average meter accuracy" and the customer's consumption for the previous six month period. Upon request of the customer, HUC shall test the average accuracy of the natural gas meter. A $40 trip charge may be assessed to all accounts in which the "as found average meter accuracy" is determined to be 102% or less. Natural Gas Service Work HUC personnel shall perform leak investigation and carbon monoxide testing at no charge to the customer. HUC does not perform service work on customer owned facilities. Locating Customer's Underground Utilities HUC shall locate all natural gas underground distribution and transmission facilities up to the meter at no charge to the customer or landowner. HUTCHINSON UTILITIES COMMISSION ^I'xP61Tti'°" Board Action Form Agenda Item: Approve Audit Services Presenter: Jared Martig Agenda Item Type: Time Requested (Minutes): 2 New Business Attachments: No BACKGROUND/EXPLANATION OFAGENDA ITEM: Audit services for fiscal year 2025 was quoted at by Conway Deuth & Schmiesing at $31,250. Below is a history of audit fees. 2024: $30,000 2023: $28,500 2022: $26,000 2021: $24,850 2020: $24,750 2019: $24,750 2018: $24,750 2017: $23,200 2016: $22,750 2015: $22,525 2014: $21,950 2013: $21,950 2012: $21,500 2011: $21,250 BOARD ACTION REQUESTED: Approve fiscal year 2025 audit services with Conway Deuth & Schmiesing Fiscal Impact: $31,250 Included in current budget: Yes Budget Change: No PROJECT SECTION: Total Project Cost: Remaining Cost: Jared Marti From: Justin McGraw <jmcgraw@cdscpa.com> Sent: Friday, October 10, 2025 4:19 PM To: Jared Martig Subject: RE: Audit Jared, Good afternoon! Yes, the summer went by fast but it was filled lots of fund. I hope yours was the same. Looking ahead at the Commission's 2025 audit, the fee I had in mind was $31,250, which is just over a 4% increase from 2024. Let me know if you have any thoughts on that otherwise that is what we will go with. CPA,S & ADVISORS Have a great weekend, Direct (3 0) 22 jmcgraw@cdscpa.com Visit us online at cds.cp a Upload oc e is via your erlgag,Ertwnt orgardzer CONFIDENTIALITY NOTICE: This message is intended only for the individual or entity to which it is addressed and may contain information that is privileged, confidential and exempt from disclosure under applicable law. if you are not the intended recipient, or ointended recipient, you are hereby notified that any dissemination, distribution or copying of this communication*1!- and you are requested to please notify us immediately by either e-mail or telephone, and return the original message to us at the above address. Friday,# k To: Justin McGraw 4 1 Subject: Audit Hi Justin, I hope your summer went well.. Just checking in to see if you have a fee in mind for the audit, can put into our budget. Jared i Financial. a a er Hutchinson UtiLities Commission Direct: 2 -2 4-05 2 Celle 3 0-296-565 lupanwu..Lw[, tpIWA].w lwuns()ounn,gov HUTCHINSON UTILITIES COMMISSION ^I'xP61Tti'°" Board Action Form Agenda Item: Approve Requisition #010415 - B-MN Data Centers Materials Presenter: Jeremy Agenda Item Type: Time Requested (Minutes): 5 New Business Attachments: Yes BACKGROUND/EXPLANATION OFAGENDA ITEM: HUC entered into a Power Purchase Agreement with B-MN Data Centers Inc. on September 24, 2025. As part of that agreement, section 2.8 "Contribution in Aid of Construction" ("CIAC) spells out how equipment will be purchased and how those initial costs will be reimbursed over time. The equipment will be sized to deliver 20MW's of power. The Customer agrees to pay HUC as a "Contribution in Aid of Construction" ("CIAC") within 30 business days after the delivery of the equipment and before the start of construction. Upon completion of construction, the final CIAC charge shall be balanced to equal the actual costs of construction, provided that such costs do not exceed the initially agreed upon cost of $250,000. After a pattern of peak load usage establishes the average new monthly billed kW demand of Customer, not to exceed 6 months from energization, an embedded cost credit (the "Cost Credit"), will be calculated and refunded by HUC to Customer in monthly credits equaling 1/36th of the actual CIAC paid by Customer until repaid in full. Cost Credit refunds will only be provided to Customer on the monthly bills from HUC if Customer is current on utility accounts. BOARD ACTION REQUESTED: Approve Requisition #010415 Fiscal Impact: Included in current budget: No Budget Change: No PROJECT SECTION: Total Project Cost: $250,000 Remaining Cost: $132,070 IHI UT iU H II HI S U HII UT'IIILIITIIIE'S a I(,� ii'JG 11�p Ili II I! � �a II ii';� If1i WESCO RECEIVABLES CORP LOCKBOX 771751 1751 SOLUTIONS CENTER DR CHICAGO, IL 60677 Note Description: 1200 amp Switchgear PURCHASE REQUISITION HUTCHINSON UTILITIES COMMISSION 225 MICHIGAN ST SE HUTCHINSON, MN 55350 Phone:320-587-4746 Fax:320-587-4721 Date Requisition No. 10/15/2025 010415 Required by: Requested by: dhunstad Item Part No. Description Qty Unit Due Date Unit Price Ext. Amount No. PSE-10-44400-1200-DB 600/600 - MFG. PART: 1 2.00 EA $41,549.000 $83,098.00 BOM PREWIRE 15KV PRIMARY METERING MFG. 2 PART: 1.00 EA $31,217.000 $31,217.00 GS-80-54-36B-MG-62X34 PAD - MFG. PART: 3 1.00 EA $3,615.000 $3,615.00 Total: 117,930.00 Date Printed: 10/16/2025 Requisitioned By: dhunstad Page: 1/1 A wesco www.anixterpowersol utions. com To: Hutchinson Utilities Attn : Phone: Fax: TRITON PADMOUNT CABINET 2208 S. 14th Street 15KV PRIMARY PAD MOUNT Mattoon, IL 61938 HUTCHINAON UTILITIES Phone: 217.235.0546 Fax: 217.258.6630 Quotation: 000792001.01 Issued Date: Oct 15, 2025 Expiration Date: Nov 14, 2025 1 BOM PREWIRE 1 PREWIRE 15KV PRIMARY METERING CABINET FROM TRITON; 2 LINE 2 LOAD 600A BUSHING; FOR (3) 1000:5 RITZ 112026163.149031 CT'S, (3) 70:1 RITZ 121531009.395006 PT'S, PREWIRED #12 WIRE; 13T SOCKET MOUNTED ON THE SIDE; WESCO STANDARD COLOR CODE DEL: —10-12 WEEKS 2 GS-80-54-36 B-M G-62X34 1 PAD BOX 80WX54DX36H MUN GRN 62X34 OPEN APMP DUR STD PKG: 7 DEL: —3 WEEKS FREIGHT TO BE ADDED Special Notes 1) All items are In Stock unless otherwise noted. 2) All item pricing on this quote is valid for thirty days unless otherwise specified 3) All applicable taxes apply. 31,217.00 EA 31,217.00 3,615.00 EA 3,615.00 SECTION TOTAL: QUOTE TOTAL: $34,832.00 BY ACCEPTING THIS QUOTE, YOU AGREE THE WESCO TERMS CONDITIONS PUBLISHED AT WWW.WESCO.COM/TERMSOFSALE ARE EXPRESSLY INCORPORATED INTO AND GOVERN THIS TRANSACTION. Storage transport fees may apply if delivery isn't accepted Min 90 days of availability. Price subject to change based on duties, freight, tariffs, or supplier increases. Anixter Power Solutions offers the industry's most extensive and dynamic portfolio of products, services and solutions for the Public Power, Investor -owned Utilities, Construction and Industrial markets. Powered by www.proquote-solutions.com Page 1 of 1 FP QUOTATION TO: Hutchinson Utilities Commission DATE: October 13, 2025 SUBJECT: RFQ for Hutchinson Utility FP Quotation #: 550421-Rl TOTAL NUMBER OF PAGES 3 (including this sheet) THE FOLLOWING BILL OF MATERIAL CONSTITUTES OUR COMPLETE OFFERING; NO OTHER WRITTEN SPECIFICATIONS WILL APPLY. Item Qtv Description 1 2 PSE-10-44400-1200-DB 600/600 15KV, 95KV BIL, Dead -front, Air Insulated, Padmounted Switchgear with four (4) 3-pole 1200 amp group operated Auto -jet switches provided with dual dead -break 600 amp bushings. DB - Dual 600amp bushings in each switch compartment only. Price..............................................................$41,549.00 each Net Adders (If Required): Item 1 1. As Required: As Required: As Required: FP-3097 Fuse End Fittings Price.............................................................$415.00 each SMU-20 Fuse units Price..............................................................$315.00 each LBI215 Load Break Inserts (200 amp Compartments) Price..............................................................$75.00 each Comments and Clarifications: This quotation is based upon information supplied to the Factory, which may or may not have been complete. Customer is responsible for reviewing this quotation for compliance, deviations, exclusions, and improper information supplied. If you feel an error or omission has been made, please contact Factory immediately. Elbows are not included as a part of our proposal. This quotation is valid for 30 days. In the event you delay the Shipment Date for any reason, we reserve the right to revise the prices listed herein or revoke the quote in its entirety.. Due to the evolving nature of tariffs, please note that the prices quoted may be subject to change as they do not include any taxes, tariffs or duties associated with the transaction. We will continue to closely monitor the situation and will promptly common icate any adjustments that may arise. Taxes/Tariffs/Duties: Prices as quoted are exclusive of all taxes, tariffs and duties which may relate in any way to the transaction. In addition to any price specified, Purchaser shall pay any present or future sales, use, excise, value added or similar tax, and any tariffs and duties applicable to the price, sale or delivery of any products furnished. Federal Pacific Quotation # 550421-R1 Date: October 13, 2025 Normal shipments shall begin within approximately 35-36 weeks after our acceptance of your formal purchase order so long as you have provided all technical details and data required to release the equipment for manufacture (the "Shipment Date"). If a better shipping schedule is required, please consult the Factory for review of our current manufacturing schedule. When drawing approval is required, the Shipment Date will be delayed by the time necessary for the drawing approval process. Approval drawings (if required) will be submitted within approximately 3-4 weeks after our acceptance of an order. Hold for approval orders not released within 30 days shall be reviewed and subject to price increases. The Shipment Date is subject to change at time of order release based on current production backlog. Freight Terms (1) Freight will be EXW Factory with seller paying freight. (2) The seller will determine the method of transportation and the routing of the shipment. Where the purchaser requires shipment by a method of transportation or routing other than that of the seller's selection, any additional transportation and/or packing expense is to be borne by the purchaser. BORDER STATES Border States - ABV 11927 53rd Street NE Albertville MN 55301-3964 Phone: 763-497-6800 HUTCHINSON UTILITIES COMMISSION 175 MICHIGAN ST SE HUTCHINSON MN 55350-1935 Quote Page: 1 of 3 Quote: 2821 1915 Sold -To Acct #: 5004 Valid From: 10/13/2025 To: 10/20/2025 PO No: Al DATA CENTER PO Date: 10/13/2025 Payment Terms: NET 25TH PROX (31) Created By: Mandy Hammar Tel No: 612-345-9288 Fax No: Inco Terms: FOB PREPAID & CHARGE FREIGHT Ship -to: HUTCHINSON UTILITIES COMMISSION 175 MICHIGAN ST SE HUTCHINSON MN 55350-1935 Cust Item Item Material Quantity Price Per UoM Value MFG - Description 000010 2 EA 35,423.66 / 1 EA 70,847.32 - PSE-11-44312-DB 600/600-1200 ESD LEAD TIME 42-44 WEEKS ARO, PLUS TRANSIT, PLUS FREIGHT FEDERAL PACIFIC PSE-11-44312-DB 600/600-1200 15KV, 95KV BIL, Dead -front, Air Insulated, Padmounted Switchgear with three (3) 3-pole 1200 amp group operated Auto -jet switches provided with dual dead -break 600 amp bushings (two (2) per phase) and one (1) 3-phase set(s) of fuse mountings for SMU-20 fuses provided with 200 amp bushing wells (one (1) per phase). Includes: DB - Dual 600/600 amp bushings on each switch compartment. NOTE: Fuse compartment shall have 200amp bushing wells. 600amp bushings are not available for fuse compartments. The maximum fuse available for PSE model dead front units is 200amps Important note, we cannot supply the fuse compartments with 600amp as the max fuse size on PSE is 200amp FP Quotation #: 550401 000011 2 EA 42,889.25 / 1 EA 85,778.50 - PSE-10-44400-1200-DB 600/600 ESD LEAD TIME 37-38 WEEKS ARO, PLUS TRANIST, PLUS FREIGHT PSE-10-44400-1200-DB 600/600 15KV, 95KV BIL, Dead -front, Air Insulated, Padmounted Switchgear with four (4) 3-pole 1200 amp group operated Auto -jet switches provided with dual dead -break 600 amp bushings. DB - Dual 600amp bushings in each switch compartment only. Border States - ABV 11927 53rd Street NE Albertville MN 55301-3964 Phone: 763-497-6800 Quote Page: 2 of 3 Quote: 28211915 Sold -to Acct #: 5004 Valid From: 10/13/2025 To: 10/20/2025 Cust Item Item Material Quantity Price Per UoM Value MFG - Description 000012 1 EA 69,363.44 / 1 EA 69,363.44 - PMDF-315-R12-600/600 - 1200 ESD LEAD TIME 50-52 WEEKS ARO, PLUS FREIGHT PMDF-315-R12-600/600 - 1200 15KV, 95KV BIL, Three -Phase, Dead -Front, Air Insulated, Primary Metering Cabinet for Radial Feed. Includes the following. 6 - 600-Amp bushings on the line side (two (2) per phase) 6 - 600-Amp bushings on the load side (two (2) per phase) 3 - Outdoor rated Current transformers-500:5 ratio. 3 - Outdoor rated Voltage transformers-70:1 ratio or equal. 1 - Form 9S, 13 teminal meter socket with test switch provisions. 1 - 10-Pole Test Switch 000013 1 EA 69,363.44 / 1 EA 69,363.44 - PMDF-315-R12-600/600 - 1200 Description 1 1 PMDF-315-R12-600/600 - 1200 15KV, 95KV BIL, Three -Phase, Dead -Front, Air Insulated, Primary Metering Cabinet for Radial Feed. Includes the following. 6 - 600-Amp bushings on the line side (two (2) per phase) 6 - 600-Amp bushings on the load side (two (2) per phase) 3 - Outdoor rated Current transformers- 15KV, 1000:5 ratio. 3 - Outdoor rated Voltage transformers-15KV, 70:1 ratio or equal. 1 - Form 9S, 13 teminal meter socket with test switch provisions. 1 - 10-Pole Test Switch ESD LEAD TIME 50-52 WEEKS ARO, PLUS FREIGHT FP Quotation #: 550449-R1 000020 1 EA 275.07 / 1 EA 275.07 - Ritz DCAB 110601001.0149 ESD LEAD TIME 9-11 WEEKS ARO, PLUS TRANSIT, PLUS FREIGHT Ritz DCAB 110601001.0149 600:5, No Base, 0.15130.1, 2.0/1.5 TRF Border States - ABV 11927 53rd Street NE Albertville MN 55301-3964 Phone: 763-497-6800 To access Border States Terms and Conditions of Sale, please go to https://www.borderstates.com The quoted sales tax is an estimate only based upon the information provided in this quote and will be finalized at the time of Invoice based upon the material purchased, quantity purchased, and delivery location. Shipping and handling fees in this quote are an estimate only and will be finalized at the time of Invoice. Quote Page: 3 of 3 Quote: 28211915 Sold -to Acct #: 5004 Valid From: 10/13/2025 To: 10/20/2025 Total $ 295,627.77 State Tax $ 6.875 %20,324.41 County Tax $ 0.000 % 0.00 Local Tax $ 0.000 % 0.00 Other Tax1 $ 0.000 % 0.00 Other Tax2 $ 0.000 % 0.00 Other Tax3 $ 0.000 % 0.00 Tax Subtotal $ 6.875 % 20,324.41 Net Amount $ 315,952.18 All clerical errors contained herein are subject to correction. In the event of any cost or price increases from manufacturers or other suppliers, caused by, but not limited to, currency fluctuations, raw material or labor prices, fuel or transportation cost increases, and any import tariffs, taxes, fees, or surcharges, Border States reserves the exclusive right to change its pricing at the time of shipping and will provide notice of any such change to its customers prior to costs being incurred. HUTCHINSON UTILITIES COMMISSION ^I'�xP61Tti'°" Board Action Form Agenda Item: Approve Level of Carbon Free/Renewable Power Supply for 2026 Presenter: Jeremy Carter Agenda Item Type: Time Requested (Minutes): 5 New Business Attachments: Yes BACKGROUND/EXPLANATION OFAGENDA ITEM: Each Year HUC is required to notify Missouri River Energy Services (MIRES), HUC's wholesale supplier on the participation level for carbon free/renewable energy for the upcoming year. The requirement deadline is Nov 1, 2025 of this year. MIRES through the Bright Energy Choices program sets aside current carbon free & renewable attributes from either currently owned assets, market purchases or bilateral contracts for carbon free/renewable energy from other companies. MIRES maintains an inventory of Renewable Energy Credits (REC's) that are used to meet State regulatory compliance or local municipal utility carbon free/renewable energy goals. For the coming year of 2026, HUC is starting off with 25% Carbon Free Energy before purchasing additional REC's. This is a decrease of 9% from 2025 where HUC started with 34% Carbon Free energy. The 9% reduction is from a reduction in nuclear REC's (7%) and a reduction in Market purchases that can be claimed as renewable (2%). Attached is a summary table of various options to consider that will impact the 2026 budget. 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