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09-27-2017 HUCCPHUTCHINSON UTILITIES COMMISSION AGENDA REGULAR MEETING September 27th, 2017 3:00 p.m. 1. CONFLICT OF INTEREST 2. APPROVE CONSENT AGENDA a. Approve Minutes b. Ratify Payment of Bills 3. APPROVE FINANCIAL STATEMENTS 4. OPEN FORUM 5. COMMUNICATION a. City Administrator b. Divisions C. Legal d. General Manager 6. POLICIES a. Review Policies i. Automatic Bill Payment Plan ii. Required Clothing iii. Small Hand Tools iv. Safety Glasses b. Approve Changes i. Errors in Billing ii. Payment of Your Bill iii. Recognition Policy -Service Awards and Retirement Gifts 7. UNFINISHED BUSINESS a. Update on Pack Gas Discussions 8. NEW BUSINESS a. Approve Bond Resolution b. Declare Surplus Items 9. ADJOURN MINUTES Regular Meeting — Hutchinson Utilities Commission Wednesday, August 30, 2017 Call to Order — 3:00 p.m. President Monty Morrow called the meeting to order at 3:00 p.m. Members present: President Monty Morrow; Vice President Anthony Hanson; Secretary Mark Girard; Commissioner Robert Wendorff; and Commissioner Don Martinez. Others present: General Manager Jeremy Carter; Attorney Marc Sebora. 1. Conflict of Interest There were no conflicts of interest noted. At this time, President Morrow added the following items to the New Business section of the agenda: 8b. Consideration of setting the annual customer appreciation event scheduled for October 3, 2017, from 4:00 to 7:00 p.m. as a Commission open meeting. 8c. Consideration to proceed with the process to retire the 2003 bonds 2. Approve Consent Agenda a. Approve Minutes — The minutes from the July 26, 2017, regular meeting were corrected as follows: Item 3 — Financial Statements Motion by Commissioner Wendorff, second by Commissioner Martinez, to approve the GGRGeRt AgeRda financial statements. b. Ratify Payment of Bills Motion by Martinez, second by Wendorff to approve the Consent Agenda with the noted correction to the meeting minutes. Motion carried unanimously. 3. Approve Financial Statements General Manager Carter presented the financial statements. Through July 2017, the general financial numbers are comparable to the 2016 figures. Revenues are up in the Electric division due in part to the recent application of power adjustments. Market sales are up and capacity contracts are tracking higher than 2016. Electric usage was up in July and the year to date usage is now trending close to the 2016 figures. The Natural Gas division continues to perform well financially. Gas consumption is up about 5% over the same period in 2016. Cash balances have also increased. Commissioner Hanson commented that purchased power is on an upward trend. Growth accounts for approximately 5% of division revenues. He suggested that the Commission have a future conversation when appropriate, possibly in 2018, regarding the HUC's position and philosophy on purchased power. Jared Martig, Financial Manager, noted that current purchased power numbers are below the figures from two years previous. Mr. Carter noted this will be part of the budget discussion for 2018. He added he will attempt to revisit the energy contract with our wholesale supplier in an effort to reduce the purchased power costs. Great River Energy (GRE) drives the transmission improvements in our area/zone, so options for Hutchinson Utilities (HUC) to be involved in future transmission ventures may likely not be available. The current contractual agreements in place limit HUC's ability to maximize revenues in these areas. Commissioner Hanson also noted that HUC will need to see how the 2018/2019 load grows, particularly in the commercial industrial sector. There may not be as great a need to focus on purchased power and/or transmission revenues, if an increase in our local load is realized and the costs to provide power to our customers, whether purchasing or generating are reasonable. Motion by Hanson, second by Girard to approve the financial statements. Motion carried unanimously. 4. Open Forum -none 5. Communication a. City Administrator— Matt Jaunich i. Mr. Jaunich communicated that the first open house was recently held by MNDot for the Trunk Highway 15/Main Street project scheduled for 2020. ii. A site plan was approved for the hotel project to be constructed at the TH 7/15 intersection. iii. A contingent from the City toured the Uponor facilities in Apple Valley. The City is excited about Uponor becoming part of the Hutchinson community. Uponor noted that they desire to partner with local utilities on renewables. b. Divisions i. Dan Lang, Engineering Services Manager — 3M is performing a shutdown on Labor Day. HUC line crew staff will be completing maintenance work. The process has started to retire Unit #2 at Plant 1 to make room for the new units and auxiliary equipment. Unit #2 is generally out of use and only used in emergency situations. ii. Dave Hunstad, Electric Transmission/Distribution Manager — Staff has completed work on the Roberts Rd and High School projects. September work will include the feed for the hotel project at highways 7/15 and additional work on the HTI/TDK and Uponor properties. The Mid -Country bank drive thru project in the downtown area requires a transformer relocation. iii. Randy Blake, Production Manager — Staff are removing Unit #2 as previously noted. HUC will attempt to sell components of Unit #2 if demand exists. Mr. Blake continues to work with Caterpillar and HDR representatives on the generator project. iv. Jared Martig, Financial Manager — Continuing to work to address minor issues with the new integrated software. He noted that the graph contained on customer bills is not accurate, but is accurate on the website. The graph will likely be removed from the bills to eliminate any confusion. c. Legal — Marc Sebora — nothing to report. d. General Manager — Jeremy Carter i. Mr. Carter continues work related to the generator project. 2 ii. He is working with the City and the financial advisors on the pending bond sale. iii. Work continues with the rate study and the consultant. iv. The 2018 budgeting process will begin in the near future. 6. Policies a. Review Policies i. Terminating Electric/Natural Gas Service by Customer ii. Retirement Program iii. Deferred Compensation iv. Personal Use of Utility Facilities & Equipment b. Approve Changes i. Cold Weather Rule — 2009 is stricken and changed to 2016 statutes ii. Definition of Your Bill — updated to coincide with the new billing system Motion by Girard, second by Martinez, to approve the policy changes as recommended. Motion carried unanimously. 7. Unfinished Business a. Update of Pack Gas Discussions General Manager Carter noted there is no new information to report at this time. 8. New Business a. Approval on Capacity Contracts Mr. Carter noted that the Commission discussed the capacity contracts at the regular meeting in July. HUC is looking to enter into two contracts, 5MW and 20MW, with AEP Energy Partners, Inc. (AEP) to maximize revenues and offset costs. Mr. Carter reviewed the chart illustrating the current and pending contract distribution contained in the packet materials. It is requested that the Commission consider for approval the two capacity contracts. Mr. Carter noted that the supplemental agreement is already in place with AEP that does not require any additional action. The contract documents were reviewed by staff and legal counsel and deemed appropriate. Motion by Girard, second by Hanson, to approve the capacity contracts. Motion carried unanimously. b. Set open meeting for the Hutchinson Utilities customer appreciation event on October 3, 2017, from 4:00 — 7:00 p.m. Motion by Hanson, second by Wendorff, to set an open meeting for the October 3rd Customer Appreciation event. Motion carried unanimously. c. Consideration to Proceed with the Process to Retire the 2003 Bonds 3 Mr. Carter reviewed that HUC is looking to issue new bonds with the recently approved generator purchase project. It is appropriate to entertain the option to redeem the 2003 bonds at this time, as funds are available and to save on interest costs. If so directed to proceed, Mr. Carter will draft the necessary resolution for Hutchinson City Council consideration. The principal remaining on the bonds is $590,000. Total principal and accrued interest costs to retire the bonds will likely total approximately $600,000. The early payoff may positively affect HUC's bond rating and ability to achieve a more favorable interest rate for the new generator project. The new bond issue affects the Electric Division. The existing Natural Gas Division bonds have a 2026 redemption date. Commissioner Martinez inquired if the anticipated Interest rate on the new bonds is lower than the rate on the existing bonds. Mr. Carter confirmed it is anticipated that they will be lower. Commissioner Hanson asked if there are any concerns from a cash flow perspective if the bonds are retired at this time. Mr. Carter indicated the cash balance should be adequate, and the anticipated outcome of implementing recommendations from the rate study should put HUC in an even more acceptable cash position than currently exists. HUC can defer the repayment of principal on newly issued bonds, but not on interest payments, if a future cash issue arises. President Morrow asked if the Commission would like to entertain consideration of the bond retirement process or defer the item to the regular September 2017 meeting. The consensus of the Commission is to act on the request at this time. Motion by Martinez, second by Hanson, to approve proceeding with the process to retire the 2003 bonds. Motion carried unanimously. 9. Adjourn There being no further business, a motion was made by Girard, second by Hanson, to adjourn the meeting at 3:36 p.m. Motion carried unanimously. ATTEST: Monty Morrow, President 12 Mark Girard, Secretary MINUTES Special Meeting — Hutchinson Utilities Commission Tuesday, August 29, 2017 Call to order — 7:00 a.m. President Morrow called the meeting to order. Members present: President Monty Morrow; Vice President Anthony Hanson; Secretary Mark Girard; Commissioner Robert Wendorff; Commissioner Don Martinez; Attorney Marc Sebora; General Manager Jeremy Carter. Others present: Jim Booty (HDR), Mark Reuter (Caterpillar), Josh Klopp (Wartsila), Dan Lang, Randy Blake, Jared Martig and Angie Radke. The purpose of the special meeting is the consideration of Awarding the Units 6 and 7 Generator Bid and Authorizing the Bonding Pre -Sale to finance the purchase and installation of the generation sets for Units 6 and 7. General Manager Carter presented two bid proposals that were furnished by Wartsila and Caterpillar. Both proposals were reviewed as to equipment provided, site suitability, technical offerings and environmental compatibility. Both companies adequately responded to additional requests or clarifications and both companies were considered responsible bidders. Staff visited SMMPA facilities that housed CAT engines to get a comfort level with these types of units and to ensure there would be no concerns or operational issues with CAT units. This proper due diligence was essential because staff is unfamiliar with running CAT engines compared to Wartsila engines which HUC currently has in place with Unit 5. Staff also ensured both engine manufacturers could deliver on their performance standards and bid proposals. Since HUC will be tax exempt on the generating units staff will need to provide a tax -exemption certificate to the engine manufacturer who is awarded the bid. Total bid price for Wartsila came in at $10,480,630, total bid price for CAT came in at $8,918,659. This is a cost difference of $1,561,971 (14.9% Margin between bids). Both companies have comparable technical quality and ability to meet the specifications of the bids documents, so HDR & staff are recommending moving forward with the lowest bid offer, which is CAT. General Manager Carter asked the board if they had any questions. Commissioner Hanson asked how many different engines we have. Mr. Blake indicated that we have many types; it is typical to have different brands of engines. In the past, it has always been which manufacturer had the best price. We are able to run anything and fix anything. Without further questions, General Manager Carter recommended Awarding the Bid to CAT. Motion by Hanson, second by Girard, to approve Awarding the Bid to CAT. Motion carried unanimously. General Manager Carter presented scenarios Authorizing the Bonding Pre -Sale to finance the purchase and installation of the generation sets for Units 6 and 7. Estimated total project costs is $16.6M. GM Carter reviewed "Wrap" versus "Level" P & I Payment Structure. With a Wrap structure, HUC would have a ceiling on HUC's total annual debt service payments but this option would back load larger principal payments on the new bond issue increasing overall interest expense over the life of the bonds. Gas currently has the largest debt service; however the gas division is in strong financial position and will continue to pay down that debt. The wrap structure is not recommended since HUC does not issue bonds on a regular basis and because HUC would end up paying more in the end. Staff also looked at a Level Annualized structure, with options to defer principal payments to any given year. Deferring principal payments can help limit cash outlay on the front end and with a level debt structure; it mirrors HUC's incoming cash flow consistently, and minimizes interest. General Manager Carter recommends issuing a 20 -year bond, this term will mirror up with the - 20 -year capacity contract. In the future, there is also a clause where both parties can exercise an additional up to 10 -year extension. The range recommendation is $16.6- 16.8M with the first principal payment - December 2019. Ehler's P & I estimates are $1,230,000, RLU Capacity Revenue is $1,176,000; which is a net difference of $54K annually. Estimated Total P & I over 20 years is $23,876,646. Revenue Contract over 20 years is $23,520,000. With $16.6M bonds, the contract will pay about 98% of the project. Estimated timeline on Engines 8-9 Months. Puts the engines on schedule to have running by fall of 2018. Commission Girard inquired with the $16.6-$16.8, would we have critical spares in that. General Manager Carter explained we would just have the Core in the amount, and have cash to pay critical spares. This way we are not paying interest on spares and it will bring the financing cost down to the $16.6M target The Commission expressed their support of the approach going with the `Level' P & I Debt Payment Schedule. After discussion, General Manager Carter asked the commission if they want to continue to move forward on financing the project. The Bond Financing Timetable is August 29th have Commission Approve Bond Financing. September 12th the city council will look to approve Bond "Pre -Sale". September 21St — September 27th Rating Evaluation, they will assess HUC's bond rating. September 26th Preliminary Offering released to market, and start getting bids back. September 27th HUC resolution approved concurring to the City's upcoming Bond Resolution to move forward and award the bonds. October 10th Bond Sale & final resolution awarding bonds at City Council. End of October/Early November Bond closing and proceeds wired. General Manager Carter suggested for the Board to consider paying off the 2003B bonds. If it is considered, we need to let bond holders know 30 day in advance. President Morrow asked the Commission if there were any other questions. Motion by Commissioner Girard, second by Commissioner Martinez to approve Authorizing the Bonding Pre -Sale to finance the purchase and installation of the generation sets for Units 6 and 7. Motion was unanimously carried. (HUC Generation Project attached.) At this time, President Morrow acknowledged and thanked General Manager Carter and the staff for all the work and due diligence that was done by everyone. There being no further business, a motion was made by Commissioner Martinez, seconded by Commissioner Wendorff to adjourn the meeting at 7:38 a.m. Motion was unanimously carried. 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HUTCHINSON UTILITIES COMMISSION COMBINED DIVISIONS FINANCIAL REPORT FOR AUGUST, 2017 2017 2016 Di %Chnq 2017 2016 Di %Chnq Full Yr Bud %of Bud Combined Division $ 23,597,974 $ 23,254,618 $ 343,357 1.5% $ 36,743,052 Customer Revenue $ 2,838,314 $ 3,068,125 $ (229,811) Sales for Resale $ 196,950 $ 326,746 $ (129,797) NU Transportation $ 70,535 $ 75,454 $ (4,920) Electric Division Transfer $ 54,308 $ 53,931 $ 378 Other Revenues $ 77,157 $ 48,148 $ 29,008 Interest Income $ 11,870 $ 2,210 $ 9,660 TOTAL REVENUES $ 3 249 134 $ 3 574 615 $ (325 481) Salaries & Benefits Purchased Commodities Transmission Generator Fuel/Chem. Depreciation Transfers (Elect./City) Operating Expense Debt Interest TOTAL EXPENSES NET PROFIT/(LOSS) $ 471,686 $ 482,398 $ (10,712) $ 1,608,408 $ 1,699,794 $ (91,386) $ 289,042 $ 351,805 $ (62,763) $ 144,853 $ 322,503 $ (177,649) $ 317,333 $ 313,000 $ 4,333 $ 154,003 $ 150,657 $ 3,345 $ 151,446 $ 209,220 $ (57,773) $ 63,382 $ 67,676 $ (4,294) $ 3,200,153 $ 3,597,053 $ (396,900) $ 48,981 $ (22,438) $ 71,419 (7.5%) $ 23,597,974 $ 23,254,618 $ 343,357 1.5% $ 36,743,052 64.2% (39.7%) $ 1,451,851 $ 1,329,048 $ 122,803 9.2% $ 2,310,110 62.8% (6.5%) $ 572,481 $ 520,356 $ 52,125 10.0% $ 734,878 77.9% 0.7% $ 434,466 $ 431,444 $ 3,022 0.7% $ 651,700 66.7% 60.2% $ 483,011 $ 422,112 $ 60,900 14.4% $ 498,808 96.8% 437.2% $ 91,340 $ 29,354 $ 61,987 211.2% $ 100,000 91.3% (9.1%) $ 26,631,124 $ 25,986,931 $ 644,193 2.5% $ 41,038,548 64.9% (2.22%) $ 3,699,256 $ 3,816,384 $ (117,128) (3.1%) $ 6,005,227 61.6% (5.4%) $ 13,487,842 $ 12,958,364 $ 529,479 4.1% $ 20,990,267 64.3% (17.8%) $ 1,926,308 $ 1,498,364 $ 427,944 28.6% $ 2,550,000 75.5% (55.1%) $ 705,862 $ 939,648 $ (233,786) (24.9%) $ 1,249,801 56.5% 1.4% $ 2,538,667 $ 2,504,000 $ 34,667 1.4% $ 3,808,000 66.7% 2.2% $ 1,232,020 $ 1,193,213 $ 38,807 3.3% $ 1,700,647 72.4% (27.6%) $ 1,495,943 $ 1,420,587 $ 75,356 5.3% $ 2,583,006 57.9% (6.3%) $ 507,058 $ 541,408 $ (34,350) 6.3% $ 760,588 66.7% (11.0%) $ 25,592,956 $ 24,871,968 $ 720,988 2.9% $ 39,647,536 64.6% 318.3%)l 1,038,168 $ 1,114,963 $ (76,795) (6.89%) $ 1,391,013 74.6% August August YTD YTD 2017 HUC 2017 2016 Change 2017 2016 Change Budget Target Gross Margin % 28.1% 26.4% 1.6% 31.0% 32.8% -1.8% 30.0% IIIIIIIIIIII� Operating Income Per Revenue $ (%) 1.4% 0.6% 0.9% 4.2% 5.4% -1.2% 4.5% Net Income Per Revenue $ (%): 1.5% -0.6% 2.1% 3.9% 4.3% -0.4% 3.4% HUTCHINSON UTILITIES COMMISSION ELECTRIC DIVISION FINANCIAL REPORT FOR AUGUST, 2017 Salaries & Benefits $ 370,563 $ 382,777 2017 2016 $ 2E %Chng 2017 2016 $ 4,727,135 2E %Chna Full Yr Bud %of Bud Electric Division (6.2%) $ 9,744,271 $ 9,371,445 $ 372,826 4.0% $ 14,208,043 68.6% Transmission $ 289,042 $ 351,805 $ (62,763) Customer Revenue $ 2,438,635 $ 2,666,670 $ (228,035) (8.6%) $ 17,119,619 $ 17,007,661 $ 111,958 0.7% $ 25,185,461 68.0% Sales for Resale $ 196,950 $ 326,746 $ (129,797) (39.7%) $ 1,451,851 $ 1,329,048 $ 122,803 9.2% $ 2,310,110 62.8% Other Revenues $ 50,432 $ 27,610 $ 22,822 82.7% $ 288,881 $ 255,517 $ 33,365 13.1% $ 280,200 103.1% Interest Income $ 5,935 $ 1,105 $ 4,830 437.2% $ 45,670 $ 14,677 $ 30,993 211.2% $ 50,000 91.3% TOTAL REVENUES $ 2,691,952 $ 3,022,132 $ (330,180) (10.9%) $ 18,906,022 $ 18,606,902 $ 299,119 1.6% $ 27,825,771 67.9% Salaries & Benefits $ 370,563 $ 382,777 $ (12,215) (3.2%) $ 2,895,566 $ 2,986,604 $ (91,038) (3.0%) $ 4,727,135 61.3% Purchased Power $ 1,379,077 $ 1,470,482 $ (91,405) (6.2%) $ 9,744,271 $ 9,371,445 $ 372,826 4.0% $ 14,208,043 68.6% Transmission $ 289,042 $ 351,805 $ (62,763) (17.8%) $ 1,926,308 $ 1,498,364 $ 427,944 28.6% $ 2,550,000 75.5% Generator Fuel/Chem. $ 144,853 $ 322,503 $ (177,649) (55.1%) $ 705,862 $ 939,648 $ (233,786) (24.9%) $ 1,249,801 56.5% Depreciation $ 233,333 $ 225,000 $ 8,333 3.7% $ 1,866,667 $ 1,800,000 $ 66,667 3.7% $ 2,800,000 66.7% Transfers (Elect./City) $ 123,408 $ 116,803 $ 6,605 5.7% $ 987,266 $ 926,594 $ 60,672 6.5% $ 1,333,516 74.0% Operating Expense $ 98,843 $ 151,039 $ (52,196) (34.6%) $ 1,057,252 $ 999,769 $ 57,483 5.7% $ 1,746,330 60.5% Debt Interest $ 2,124 $ 2,551 $ (427) (16.7%) $ 16,992 $ 20,408 $ (3,417) 16.7% $ 25,488 66.7% TOTAL EXPENSES $ 2,641,243 $ 3,022,960 $ (381,716) (12.6%) $ 19,200,183 $ 18,542,833 $ 657,351 3.5% $ 28,640,313 67.0% NET $ 50,709 $ (8228y�)) 51(((,536 (6,226.9%) $ (294,162) $ $ (355/8,2(((31) (559.1%) $ (814,542) 36.1% �PPROFIIT/(LLOSS(()((( / �y64,0770(� 66.7% of Year Comp. 2017 2016 2E %Chna 2017 2016 2E %Chna Full Yr Bud %of Bud Electric Division Residential 4,523,968 5,922,220 (1,398,252) (23.61%) 33,325,598 34,666,860 (1,341,262) (3.87%) 50,432,797 66.1% All Electric 129,604 169,089 (39,485) (23.35%) 1,569,020 1,632,898 (63,878) (3.91%) 2,611,705 60.1% Small General 1,590,142 1,817,987 (227,845) (12.53%) 12,061,505 12,076,502 (14,997) (0.12%) 17,085,853 70.6% Large General 7,165,390 7,464,899 (299,509) (4.01%) 50,005,905 49,584,888 421,017 0.85% 79,262,499 63.1% Industrial 13,257,000 14,928,000 (1,671,000) (11.19%)l 92,198,000 95,076,000 (2,878,000) (3.03%) 134,707,856 68.4% Total KWH Sold 26,666,104 30,302,195 (3,636,091) (12.00%)l 189,160,028 193,037,148 (3,877,120) (2.01%)l 284,100,710 66.6% The Electric division in August 2017 had a net profit improvement of $51,536 depite low temperatures leading to decreases in both Customer Revenue and Sales for Resale. Expenses were also down across the board except for small increases in PILOT and Depreciation. Sales for Resale of $196,950 consisted of $16,388 in market sales, $34,400 in the monthly tolling fee from Transalta, $50,162 in energy sales to Transalta, and $96,000 in capacity sales to SMMPA. August 2016 Sales for Resale of $326,746 consisted of $55,154 in market sales, $34,400 in monthly tolling fees from Transalta, $170,692 in Transalta energy sales, and $66,500 in capacity sales to SMMPA. August 2015 Sales for Resale of $222,855 consisted of $18,411 market sales, $34,400 in Transalta tolling fees, $128,044 in Transalta energy sales, and capacity sales to SMMPA for $42,000. Overall Purchased Power decreased by $91,405. MRES purchases increased by $33,756 and market purchases decreased by $125,161 due to needing less. The power cost adjustment for August 2017 was $.0087/kwhr bringing in an additional $231,399 of revenue for the month and $1,220,380 for the year. Last year's power cost adjustments through August of 2016 generated $565,079 in additional revenue. August August YTD YTD 2017 HUC 2017 2016 Change 2017 2016 Change Budget Target Gross Margin % 22.9% 21.2% 1.6% 23.9% 26.4% -2.5% 22.5% Operating Income Per Revenue $ (%) 0.5% -0.1% 0.5% -2.6% 0.1% -2.7°% -3.0°% Net Income Per Revenue $ (%): 1.9% 0.0% 1.9% -1.6% 0.3% -1.9% -2.9°% IIIIIIIIIIIIIIIIIIIII Customer Revenue per KWH: $0.0915 $0.0880 $0.0034 $0.0901 $0.0877 $0.0024 $0.0881 pp Total Power Supply Exp. per KWH: $0.0767 $0.0785 -$0.0017 $0.0752 $0.0707 $0.0046 $0.0758 The Electric division in August 2017 had a net profit improvement of $51,536 depite low temperatures leading to decreases in both Customer Revenue and Sales for Resale. Expenses were also down across the board except for small increases in PILOT and Depreciation. Sales for Resale of $196,950 consisted of $16,388 in market sales, $34,400 in the monthly tolling fee from Transalta, $50,162 in energy sales to Transalta, and $96,000 in capacity sales to SMMPA. August 2016 Sales for Resale of $326,746 consisted of $55,154 in market sales, $34,400 in monthly tolling fees from Transalta, $170,692 in Transalta energy sales, and $66,500 in capacity sales to SMMPA. August 2015 Sales for Resale of $222,855 consisted of $18,411 market sales, $34,400 in Transalta tolling fees, $128,044 in Transalta energy sales, and capacity sales to SMMPA for $42,000. Overall Purchased Power decreased by $91,405. MRES purchases increased by $33,756 and market purchases decreased by $125,161 due to needing less. The power cost adjustment for August 2017 was $.0087/kwhr bringing in an additional $231,399 of revenue for the month and $1,220,380 for the year. Last year's power cost adjustments through August of 2016 generated $565,079 in additional revenue. HUTCHINSON UTILITIES COMMISSION GAS DIVISION FINANCIAL REPORT FOR AUGUST, 2017 Salaries & Benefits $ 2017 $ 99,621 2016 2E Gas Division 229,331 $ 229,312 $ 19 Operating Expense $ Customer Revenue $ 399,679 $ 401,455 $ (1,776) Transportation $ 70,535 $ 75,454 $ (4,920) Electric Div. Transfer $ 54,308 $ 53,931 $ 378 Other Revenues $ 26,724 $ 20,538 $ 6,186 Interest Income $ 5,935 $ 1,105 $ 4,830 TOTAL REVENUES $ 557,182 $ 552,483 $ 4,699 Salaries & Benefits $ 101,123 $ 99,621 $ 1,502 Purchased Gas $ 229,331 $ 229,312 $ 19 Operating Expense $ 52,603 $ 58,181 $ (5,577) Depreciation $ 84,000 $ 88,000 $ (4,000) Transfers (City) $ 30,594 $ 33,854 $ (3,260) Debt Interest $ 61,258 $ 65,125 $ (3,867) TOTAL EXPENSES $ 558,910 $ 574,093 $ (15,183) NET PROFIT/(LOSS) $ (1,728) $ (21,610) $ 19,882 1.5% $ 803,690 $ 829,780 $ (26,090) 0.0% $ 3,743,571 $ 3,586,919 $ 156,652 (9.6%) $ 438,691 $ 420,818 $ 17,874 (4.5%) $ 672,000 $ 704,000 $ (32,000) (9.6%) $ 244,754 $ 266,619 $ (21,865) 0.0% $ 490,067 $ 521,000 $ (30,933) (2.6%) $ 6,392,773 $ 6,329,136 $ 63,637 32.0%) $ 1,332,330 $ 1,050,893 $ 281,436 (3.1%) 66.7% of Year Comp. %Chng 2017 4.2% 2016 (4.5%) 2E %Chna Full Yr Bud %of Bud (0.4%) $ 6,478,355 $ 6,246,957 $ 231,398 3.7% $ 11,557,591 56.1% (6.5%) $ 572,481 $ 520,356 $ 52,125 10.0% $ 734,878 77.9% 0.7% $ 434,466 $ 431,444 $ 3,022 0.7% $ 651,700 66.7% 30.1% $ 194,130 $ 166,595 $ 27,535 16.5% $ 218,608 88.8% 437.2% $ 45,670 $ 14,677 $ 30,993 211.2% $ 50,000 91.3% 0.9% $ 7,725,102 $ 7,380,029 $ 345,074 4.7% $ 13,212,777 58.5% 1.5% $ 803,690 $ 829,780 $ (26,090) 0.0% $ 3,743,571 $ 3,586,919 $ 156,652 (9.6%) $ 438,691 $ 420,818 $ 17,874 (4.5%) $ 672,000 $ 704,000 $ (32,000) (9.6%) $ 244,754 $ 266,619 $ (21,865) 0.0% $ 490,067 $ 521,000 $ (30,933) (2.6%) $ 6,392,773 $ 6,329,136 $ 63,637 32.0%) $ 1,332,330 $ 1,050,893 $ 281,436 (3.1%) $ 1,278,092 4.4% $ 6,782,224 4.2% $ 836,676 (4.5%) $ 1,008,000 (8.2%) $ 367,131 5.92L $ 735,100 1.0% $ 11,007,223 26.8%1 $ 2,205,554 62.9% 55.2% 52.4% 66.7% 66.7% 66.7% 58.1% 60.4% August August YTD YTD 2017 HUC 2017 2016 Change 2017 2016 Change Budget Target Gross Margin % 54.2% 66.7% of Year Comp. -1.8% 2017 2016 Di %Chnq 2017 2016 Di %Chnq Full Yr Bud %of Bud Gas Division 20.6% Net Income Per Revenue $ (%): -0.3% -4.1% 3.7% 17.8% 14.6% 3.2% 17.0% Contracted Customer Rev. per CF: Residential 6,330,597 6,842,651 (512,054) (7.48%) 243,346,671 245,598,013 (2,251,342) (0.92%) 449,582,000 54.1% Commercial 10,420,668 8,827,473 1,593,195 18.05% 196,959,419 183,547,550 13,411,869 7.31% 420,183,000 46.9% Industrial 54,134,175 50,104,753 4,029,422 8.04% 555,841,398 515,265,132 40,576,266 7.87% 786,836,000 70.6% Total CF Sold 70,885,440 65,774,877 5,110,563 7.77%1 996,147,488 944,410,695 51,736,793 5.48%1 1,656,601,000 60.1% August August YTD YTD 2017 HUC 2017 2016 Change 2017 2016 Change Budget Target Gross Margin % 54.2% 56.0% -1.8% 48.9% 49.2% -0.3% 46.2% Operating Income Per Revenue $ (%) 6.1% 4.1% 2.0% 21.2% 19.3% 1.9% 20.6% Net Income Per Revenue $ (%): -0.3% -4.1% 3.7% 17.8% 14.6% 3.2% 17.0% Contracted Customer Rev. per CF: $0.0036 $0.0036 $0.0000 $0.0038 $0.0033 $0.0005 $0.0041 Customer Revenue per CF: $0.0123 $0.0142 -$0.0019 $0.0099 $0.0106 -$0.0007 $0.0096 Total Power Supply Exp. per CF: $0.0034 $0.0036 ($0.0001) $0.0038 $0.0039 ($0.0000) $0.0042 Net Loss for August 2017 decreased by $19,882 in the gas division with all revenues and expenses in line with August 2016. The fuel credit adjustment for August 2017 was $1.41638/MCF providing credits to the customers of $29,086 for the month and $419,997 for the year. Fuel credit adjustments totalled $44,625 through August of 2016. Current Assets UnrestrictedlUndesignated Cash Cash Petty Cash Designated Cash Capital Expenditures - Current Yr Payment in Lieu of Taxes Rate Stabilization - Electric Rate Stabiliation - Gas Catastrophic Funds Restricted Cash Bond Interest Payment 2003 Bond Interest Payment 2012 Debt Service Reserve Funds Total Current Assets Receivables Accounts (net of uncollectible allowances) Interest Total Receivables HUTCHINSON UTILITIES COMMISSION BALANCE SHEET - CONSOLIDATED AUGUST 31, 2017 Electric Gas Total Total Net Change Division Division 2017 2016 Total (YTD) 6,788,964.07 5,029,282.72 11,818,246.79 10,545,548.75 1,272,698.04 680.00 170.00 850.00 850.00 - 329,058.71 1,273,101.83 1,602,160.54 871,619.23 730,541.31 829,200.00 367,131.00 1,196,331.00 1,305,256.00 (108,925.00) 314,539.41 - 314,539.41 397,193.34 (82,653.93) - 646,058.37 646,058.37 577,125.53 68,932.84 400,000.00 100,000.00 500,000.00 500,000.00 - 125,406.25 - 125,406.25 112,180.91 13,225.34 - 1,629,250.02 1,629,250.02 1,260,750.11 368,499.91 - 2,188,694.02 2,188,694.02 2,188,694.02 - 8,787,848.44 11,233,687.96 20,021,536.40 17,759,217.89 2,262,318.51 2,339,450.66 463,028.46 2,802,479.12 3,214,472.41 (411,993.29) 22,224.58 9,191.09 31,415.67 - 31,415.67 2,361,675.24 472,219.55 2,833,894.79 3,214,472.41 (380,577.62) Other Assets Inventory 1,185,201.92 412,277.64 1,597,479.56 1,510,476.88 87,002.68 Prepaid Expenses (8,798.10) 41,125.28 32,327.18 110,825.71 (78,498.53) Sales Tax Receivable 170,149.19 - 170,149.19 140,184.10 29,965.09 Deferred Outflows- Electric 1,746,060.00 - 1,746,060.00 388,200.00 1,357,860.00 Deferred Outflows - Gas - 582,020.00 582,020.00 129,400.00 452,620.00 Total Other Assets 3,092,613.01 1,035,422.92 4,128,035.93 2,279,086.69 1,848,949.24 Total Current Assets 14,242,136.69 12,741,330.43 26,983,467.12 23,252,776.99 3,730,690.13 Capital Assets Land & Land Rights 690,368.40 3,901,323.35 4,591,691.75 4,590,287.00 1,404.75 Depreciable Capital Assets 89,041,537.46 41,260,565.70 130,302,103.16 129,510,003.63 792,099.53 Accumulated Depreciation (51,872,591.97) (14,997,901.36) (66,870,493.33) (63,247,667.19) (3,622,826.14) Construction - Work in Progress 1,102,675.74 251,743.25 1,354,418.99 607,032.77 747,386.22 Total Net Capital Assets 38,961,989.63 30,415,730.94 69,377,720.57 71,459,656.21 (2,081,935.64) Total Assets 53,204,126.32 43,157,061.37 96,361,187.69 94,712,433.20 1,648,754.49 Current Liabilities Current Portion of Long-term Debt Bonds Payable Bond Premium Accounts Payable Accrued Expenses Accrued Interest Accrued Payroll Total Current Liabilities Long -Term Liabilities Noncurrent Portion of Long-term Debt 2003 Bonds 2012 Bonds Bond Premium 2012 Pension Liability- Electric Pension Liability- Nat Gas Accrued Vacation Payable Accrued Severance Deferred Outflows - Electric Deferred Outflows - Nat Gas Total Long -Term Liabilities Net Position Retained Earnings Total Net Position HUTCHINSON UTILITIES COMMISSION BALANCE SHEET - CONSOLIDATED AUGUST 31, 2017 Electric Gas Total Division Division 2017 125,000.00 3,252,829.69 6,371.80 32, 595.72 3,416,797.21 465,000.00 4,226,202.00 286,389.60 66,478.09 569,910.00 5,613,979.69 1,220,000.00 185,608.32 916,580.83 183,775.15 53,857.44 2,559,821.74 15,195, 000.00 1,531,268.27 1,408,734.00 92,553.90 25,572.23 189,970.00 18,443,098.40 1,345,000.00 185,608.32 4,169,410.52 190,146.95 86,453.16 5,976,618.95 465,000.00 15,195, 000.00 1,531,268.27 4,226,202.00 1,408,734.00 378,943.50 92,050.32 569,910.00 189,970.00 24,057,078.09 Total 2016 1,285,000.00 185,608.32 4,894,755.83 203,028.23 206,801.51 6,775,193.89 590,000.00 16,415,000.00 1,716,876.59 2,775,239.00 925,080.00 356,049.33 90,772.86 396,226.00 132,076.00 23,397,319.78 44,173,349.42 22,154,141.23 66,327,490.65 64,539,919.53 44,173,349.42 22,154,141.23 66,327,490.65 64,539,919.53 Net Change Total (YTD) 60,000.00 (725, 345.31) (12,881.28) (120,348.35) (798,574.94) (125,000.00) (1,220,000.00) (185,608.32) 1,450,963.00 483,654.00 22, 894.17 1,277.46 173,684.00 57,894.00 659,758.31 1,787,571.12 1,787,571.12 Total Liabilities and Net Position 53,204,126.32 43,157,061.37 96,361,187.69 94,712,433.20 1,648,754.49 Hutchinson Utilities Commission Cash -Designations Report, Combined 8/31/2017 Checking, Investments Total Operating Funds Debt Reserve Requirements Debt Reserve Requirements Total Reserve Requirement Operating Reserve Rate Stabalization Funds PILOT Funds Catastrophic Funds Capital Reserves Total Earmarked Funds varies varies varies 20,021,536.40 20,013,046.33 8,490.07 20,021,536.40 20,013,046.33 8,490.07 Bond Covenants - sinking fund 1,754,656.27 1,579,190.63 175,465.64 Bond Covenants -1 year Max. P & 1 2,188,694.02 2,188,694.02 - 3,943,350.29 3,767,884.65 175,465.64 Min 60 days of 2017 Operating Bud. Charter Risk Mitigation Amount 5 Year CIP ( 2017-2021 Fleet & Infrastructure Maintenance) 5,973,256.00 5,973,256.00 960,597.78 960,597.78 1,196, 331.00 1,196, 331.00 500,000.00 500,000.00 3,450,000.00 3,450,000.00 12, 080,184.78 12, 080,184.78 YE YE YE YE YTD HUC Change in 2014 Financial 2016 2017 Balance, Balance, Cash/Reserve 32.0% Institution Current Interest Rate Annual Interest August 2017 July 2017 Position IA WOR 3.47 18,112,875 RONA 0.80% 0.05% 1.31% 2.17% Checking, Investments Total Operating Funds Debt Reserve Requirements Debt Reserve Requirements Total Reserve Requirement Operating Reserve Rate Stabalization Funds PILOT Funds Catastrophic Funds Capital Reserves Total Earmarked Funds varies varies varies 20,021,536.40 20,013,046.33 8,490.07 20,021,536.40 20,013,046.33 8,490.07 Bond Covenants - sinking fund 1,754,656.27 1,579,190.63 175,465.64 Bond Covenants -1 year Max. P & 1 2,188,694.02 2,188,694.02 - 3,943,350.29 3,767,884.65 175,465.64 Min 60 days of 2017 Operating Bud. Charter Risk Mitigation Amount 5 Year CIP ( 2017-2021 Fleet & Infrastructure Maintenance) 5,973,256.00 5,973,256.00 960,597.78 960,597.78 1,196, 331.00 1,196, 331.00 500,000.00 500,000.00 3,450,000.00 3,450,000.00 12, 080,184.78 12, 080,184.78 YE YE YE YE YTD HUC 2013 2014 2015 2016 2017 Target Debt to Asset 29.7% 28.8% 32.0% 32.2% 31.2% Current Ratio 2.08 2.26 2.52 3.06 3.47 18,112,875 RONA 0.80% 0.05% 1.31% 2.17% 1.23% 462,701 Due to a wire transfer not posting in July in the BS&A software before financial statements were created the July financials showed an increase in cash of roughly $1,000,000. This should have been around $600,000. The roughly break even cash for August as shown on this financial statement should be roughly $400,000 higher but year to date is correct. The offset is that A/P was higher than it should have been last month as well. Change in Cash Balance (From 12/31/14 to 8/31/2017) Month End Electric Elec. Change Natural Gas Gas Change Total Total Change 7/31/2017 8,787,848 11,233,688 20,021,536 12/31/2016 8,612,801 175,047 9,500,074 1,733,614 18,112,875 1,908,661 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 Due to a wire transfer not posting in July in the BS&A software before financial statements were created the July financials showed an increase in cash of roughly $1,000,000. This should have been around $600,000. The roughly break even cash for August as shown on this financial statement should be roughly $400,000 higher but year to date is correct. The offset is that A/P was higher than it should have been last month as well. Hutchinson Utilities Commission Cash -Designations Report, Electric 8/31/2017 Savings, Checking, Investments varies varies Total HUC Operating Funds Debt Restricted Requirements Bond Covenants - sinking fund varies 20,021,536.40 20,013,046.33 8,490.07 20,021,536.40 20,013,046.33 8,490.07 125,406.25 112,865.62 12, 540.63 Operating Reserve Min 60 days of 2017 Operating Bud. 4,306,719.00 4,306,719.00 Rate Stabalization Funds $400K -$1.2K Change in 314,539.41 Financial Charter 829,200.00 Balance, Balance, Cash/Reserve 400,000.00 InstitutionCurrent Interest Rate Annual Interest August 2017 July 2017 Position r'r 8,600,458.41 8,600,458.41 3.57 NA 1.81 Savings, Checking, Investments varies varies Total HUC Operating Funds Debt Restricted Requirements Bond Covenants - sinking fund varies 20,021,536.40 20,013,046.33 8,490.07 20,021,536.40 20,013,046.33 8,490.07 125,406.25 112,865.62 12, 540.63 Operating Reserve Min 60 days of 2017 Operating Bud. 4,306,719.00 4,306,719.00 Rate Stabalization Funds $400K -$1.2K 314,539.41 314,539.41 PILOT Funds Charter 829,200.00 829,200.00 Catastrophic Funds Risk Mitigation Amount 400,000.00 400,000.00 Capital Reserves 5 Year CIP ( 2017-2021 Fleet & Infrastructure Maintenance) 2,750,000.00 2,750,000.00 Total Designated Funds Current Ratio 2.77 8,600,458.41 8,600,458.41 VE VE VE VE APPA Ratio APPA Ratio HUC 2013 2014 2015 2016 w/10-50% Gen 5K -10K Cust. Target Debt to Asset Ratio 8.0% 7.4% 13.2% 16.1% 61.0% 29.5% Current Ratio 2.77 2.48 2.95 3.57 NA 1.81 RONA -2.7% -3.1% -1.2% -0.4% NA NA >0% Hutchinson Utilities Commission Cash -Designations Report, Gas 8/31/2017 Savings, Checking, Investments varies varies Total HUC Operating Funds Debt Restricted Requirements Bond Covenants - sinking fund Debt Restricted Requirements Bond Covenants -1 year Max. P & I Total Restricted Requirements Operating Reserve Rate Stabalization Funds PILOT Funds Catastrophic Funds Capital Reserves Total Earmarked Funds varies 20,021,536.40 20,013,046.33 8,490.07 20,021,536.40 20,013,046.33 8,490.07 Min 60 days of 2017 Operating Bud. $200K -$600K Charter Risk Mitigation Amount 5 Year CIP ( 2017-2021 Fleet & Infrastructure Maintenance) 1,629, 250.02 1,466, 325.01 162,925.01 2,188,694.02 2,188,694.02 - 3,817,944.04 3,655,019.03 162,925.01 1,666, 537.00 1,666, 537.00 646,058.37 646,058.37 367,131.00 367,131.00 Change in 100,000.00 Financial 700,000.00 3,479,726.37 Balance, Balance, Cash/Reserve 2013 InstitutionCurrent Interest Rate Annual Interest August 2017 July 2017 Position Debt to Asset 58.6% 777777M 54.8% 51.5% TBD TBD <50% Savings, Checking, Investments varies varies Total HUC Operating Funds Debt Restricted Requirements Bond Covenants - sinking fund Debt Restricted Requirements Bond Covenants -1 year Max. P & I Total Restricted Requirements Operating Reserve Rate Stabalization Funds PILOT Funds Catastrophic Funds Capital Reserves Total Earmarked Funds varies 20,021,536.40 20,013,046.33 8,490.07 20,021,536.40 20,013,046.33 8,490.07 Min 60 days of 2017 Operating Bud. $200K -$600K Charter Risk Mitigation Amount 5 Year CIP ( 2017-2021 Fleet & Infrastructure Maintenance) 1,629, 250.02 1,466, 325.01 162,925.01 2,188,694.02 2,188,694.02 - 3,817,944.04 3,655,019.03 162,925.01 1,666, 537.00 1,666, 537.00 646,058.37 646,058.37 367,131.00 367,131.00 100,000.00 100,000.00 700,000.00 700,000.00 3,479,726.37 3,479,726.37 Designations,Excess Reserves Less Restrictions & i (203,094.68) VE VE VE VE HUC 2013 2014 2015 2016 APGA Ratio APGA Ratio Target Debt to Asset 58.6% 55.6% 54.8% 51.5% TBD TBD <50% Current Ratio 1.31 2.07 2.17 2.59 TBD TBD ��IIII��IIIIIIII RONA 5.8% 4.3% 4.7% 5.6% TBD TBD w N L t i 2 C L v 7 � U ' O ( ws fC i 0 2�� 00000 Q Q Q Q N N N N N_ Q Q Q Q Q Q Q zzzz�� zzzzzzz O N N N N 0-00- -00&000N 00000N M O M N 1- O O M M N V r (O M O N W W -(C V M M V O CA (O M CA r (O (O N (O O O 00W�NrOOOU)U)U)O r(0 M M (A r M (A V M O O M r N r M N (O (O co (O 0) N N V r r 00 O r M (O •�•� M l�M M M l�l�� 00000000000 00000000O0 0 0 0 00 9999999999 N O O M M 0 0 N 000000000 O U) O U) 1- 1- 0 0 M 0000000000 M N V N (O M O N O O 0 0 0 0 0 0 0 O 0 0 0 0 M V M l n V M M M M M M O M M O O CA (O (O 0) 1- (O (O V V V V V V (O r N M (O M O M M (O r (O N N N N N N N N O O N N M N N N N O AM (\I 00 OIC) M OO M M O 0000000 O I- I- V CO O N 0 N N O 99999 M O M M M O N O 00 CA M M M O O M M N M N (O (O W(O O r r M (O M (O M 0) V (O O O CA M M In M O In (C r (C W V V V V O M M V M M V (n M M M M (O N (n M M M V V V V V V M I- N N M M O M M (O (O M N N N N N N N N O O N N M N N N N O M N 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 00100 000000666 O 0 0 0 0 0 0 0 O 0000000000 0000000O 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 O M M M M M M O M M O 00000000 V V V V V V M r- N M M M O M M M M O N N N N N N N N O O N N M N N N N O O2 O2 O2 O2 N T N M O O O T T 00 O O O O O O O 00O O O O O 0 o N N N N N N N N N M o N N N N N N N N O 00 O 1- 1- 1- M I- Ln G N N N N O N N N N 00 0 0 0 0 O N N N (n O 6 6 6 O Z W IZZ V0000- 000- 00000-0 (0 (0 (0 (0 (0 r (0 r (0 (0 (0 (0 (0 (0 (0 (0 000000000 0000000 N N N N N N N N N N N N N N N N W I -I- I- I- m I- I- I- CO M M M O O N O N N O O O N N N N N N 6V 6 6 6 OM M M V V V00000000— 00000000- 0 0 0 0 0 0 0 0 0 0 0 0 0 0 00 0 0 0 0 0 0 0 0 0 0 0 0 M N m O M O ON 0 M", 0 M M w M O N N ' O 00 r W 00') (O N . � N 0 N N N 0 0 0 0 0 0 0 0 00 o 0 0 0 0 o 000000000 O In O O 0!n O O O I n O M (O M O (A M (O co r M O N O .999 CA r W W r O N N N N N N N M M C7 F Z W m N N N N N N F -0-0-0-0 N C C C y0 w ~ C C C ~ CA CA CA co co co co m m m Z L- �- �- �- �- �- �- U U U p �� 0 J u�� a N N N N N N J J J Ln 3 3 3 3 3 3 3 Ln 0 U U U U U U LL LL LL 0 N N N N N N N N N N N N N N Nl (n (n (n (n (n (n (n C C C C C C C 0 0 0 00 0 0 0 0 N N N N N N N 0) 0) 0) 0) 0) 0) 0) 0) 0) >>>>>>> CCCCCC N N N N N N N N N LL LL LL LL LL LL LL LL LL N N N N N N N N N N N N N N N N U U U U U U U m w O + i > Nl � M M M O M N O e V (A O O M O O N N N O r i O M O O O M O O d > LL1...,,., w W W (O O O N U0 J. 7 I- I- W O W M 1-- 0 O W N oo M n M M M r CF) M W M W M N Cp (A O N O LO N rn N Qi (6 y w T J o i O d Vhf u) N M V M a -I ' + J J N M V M W O C r1 m i n r+ > of y 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 V N O O O o O w O O N ti ti ti -. o m s 0o o`R -, w ttmo M W r off° C N M O w 0 C f6 O t VT p U 2 O y 0 0 W N O N O CA O O O N co V O LO i N C O O M O O w w D O O M u0 C O (A M r LO � L N II( 411..,. N > (O M N 10 G (y r V M O O F F cy; '� � o o o0 0 C O O W N O O O CA O O O O3 �.n w o o M 10 g W r cNo > r w M M Cp V M O O III � N U I ~ N o m o Q U 1 O Co a � o (6 w _ O E N ~ c m O .� LL w w .2 w oo O (] o 3 E f0+1 U 0 � � `w [ino oM C7 ELECTRIC DIVISION Operating Revenue AUGUST 2017 CLASS AMOUNT KWH /KWH Street Lights $0.54 10 $0.05400 Electric Residential Service $472,930.60 4,523,968 $0.10454 All Electric Residential Service $14,111.44 129,604 $0.10888 Electric Small General Service $165,578.82 1,590,142 $0.10413 Electric Large General Service $696,197.47 7,165,390 $0.09716 Electric Large Industrial Service $1,089,816.10 13,257,000 $0.08221 Total $2,438,634.97 26,666,114 $0.09145 Power Adjustment $0.00870 Rate Without Power Adjustment $0.08275 Electric Division Year -to -Date 02017$Amount 02016$Amount M2017KWH/10 02016 KWH/10 22,000,000 21,000,000 20,000,000 19,000,000 18,000,000 17,000,000 16,000,000 15,000,000 14,000,000 13,000,000 12,000,000 11,000,000 10,000,000 9,000,000 8,000,000 7,000,000 6,000,000 5,000,000 4,000,000 3,000,000 2,000,000 1,000,000 0 Street Lights Residential All Elec. Small Gen. Large Gen. Large For Resale Total Resid. Srv. Srv. Industrial NOTE: Sales for resale includes capacity sales, market sales and Transalta sales. NATURAL GAS DIVISION Operating Revenue AUGUST 2017 CLASS AMOUNT MCF/$ MCF Residential $81,846.28 6,331 $12.92786 Commercial $92,381.61 10,421 $8.86495 Large Industrial $225,451.55 54,134 $4.16469 Total $399,679.44 70,886 $5.63834 Fuel Adjustment -$0.00142 Rate Without Fuel Adjustment $7.05834 Natural Gas Division Year -to -Date ® 2017 $ Amount 0 2016 $ Amount ® 2017 MCF 0 2016 MCF 10,000,000 9,000,000 8,000,000 7,000,000 6,000,000 5,000,000 4,000,000 3,000,000 2,000,000 1,000,000 0 Gas Residential Gas Commercial Large Industrial Total eReliability I Monthly Statistics Monthly Report - Hutchinson Utilities Hutchinson Utilities Commission Commission Year Minimum duration Substation 2017 Month Maximum duration Circuit 08 - August Annual Report? Top-level Cause Remove Major Events? 0 Yes ...___ V ----- v * No https:Hreliability.publicpower.org/reports/monthly/utility/91?year=2017&month=8&is an... 9/20/2017 eReliability I Monthly Statistics IEEE 1366 Statistics Metric SAID[ SAIFI CAIDI ASAI Momentary Interruptions Sustained Interruptions Circuit Ranking - Worst Performing Ranked by Outage Count Circuit Substation Fdr#16 Plant 1 Ranked by Customer Interruptions Circuit Substation Fdr#16 Plant 1 Ranked by Customer Minutes of Duration Circuit Substation Fdr#16 Plant 1 Aug 2017 Aug 2016 0.599 3.586 0.00666 0.0283 90 126.6 99.9986% 99.9916% 0 0 1 2 Number of Outages 1 Customer Interruptions UFA Customer Minutes of Duration 4,230 Page 2 of 5 https://reliability.publicpower.org/reports/monthly/utility/91?year=2017&month=8&is an... 9/20/2017 Historical Monthly 8A|O|Chart 2,0 1.5 O.5' SAIDI values 0.O Seo Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug 2018 2018 2016 2016 2017 2017 3017 2017 2017 2017 2017 2017 Historical K8onthly8A|F| Chart SAIR values 0. 00 �~_�~�~_==�___ Seo Oct Nov Dec Jon Feb Mar Apr May Jun Jul Aug 2016 2018 2016 2018 2017 2017 2017 2017 2017 2017 2017 2017 https:,//reliability.publicpower.org/reports/monthly/utility/9 0/20/2017 !11 �R!' 1111111 1 11111M ITIMPRIM, Causes Ranked by Count Cause Electrical Failure Causes Ranked by Duration Cause Electrical Failure Count Duration 4,230 https:lireliability.publicpower.org.lreportslmonthlylutilityl9l?year=2017&month=8&is an... 9/20/2017 eeliability ( Monthly Statistics Top 1 Outages for the Month Customers Address Interrupted 800 Block of Lynn 47 Td SW Total Customers Affected for the Month: Customer Minutes of Duration Interruption Start Date 90 4,230 08/05/2017 Average Customers Affected per Outage: 47 47 https:llreliability.publicpower.org,lreportslmonthlylutilityl9l?year=2017&month=8&is ... 9/20/2017 Work Order Description 11701 Plant lDoor & Window Replacement 1170I Unit #OField Breaker/Voltage Control 11703 Unit #OBoiler Non -Return Valve 11704 Plant 1Alarm Panel Upgrade 1I705 Unit #1Control System Batteries 1I706 Plant 1Electrical Panel Upgrades 11707 Unit #IGas Valve Upgrade 11708 Units 6and 7 Ir-MOMMET-7174 "M Total Total Percentage Materialsi Labor Budgeted Actual Difference Completed $ 150\000.00 $ 20,000.00 $ 170\000.00 $ 7.943.87 $(1§I'D5613) Cancel 95'000.00 5'000.00 $ 100,000.00 56,180.I2 $ (43,819.78) 50% 40,000.00 1,000.00 $ 41,000.00 I1'663.48 $ (19'336.5I) 100% lC\DDO.DD §,DOD.DD $ 10i000.00 $ (l§,DDD.DD) 0% 8,500.00 $ 8,500.00 1.816.97 $ (6'683.03) 100% l[\DDD.DD - $ 10\000.00 17I20 $ (9,827.80) D% - $ - 57,959.49 $ 57.959.49 100% ------_- $-_' 7 _37g�14.7n9 $ 379,114.79 25% $ 163,500.00 $ Il'DOO.DO $175'5DO.DD $5Ob,9O7.l5 $ 331,407.15 Electric Distribution Work Total Total Percentage Order Description Materials Labor Budgeted Actual Difference Completed 21701 Pole Repair or Replacement 15,000.00 - 15,000.00 - $ (15,000.00) 0% 21702 Hutch Substation Roof Replacement 10,000.00 - 10,000.00 - $ (10,000.00) 0% 21703 Station Equipment 10,000.00 - 10,000.00 - $ (10,000.00) 0% 21704 Poless, Towers, Fixtures N Hwy 15 Fdr 12A 10,000.00 5,000.00 15,000.00 - $ (15,000.00) 0% 21705 Right of Way Clearing 2,500.00 2,500.00 182.00 $ (2,318.00) 0% 21706 Duct for Reconductor 20,000.00 65,000.00 85,000.00 105,299.55 $ 20,299.55 95% 21707 Reconductor Feeder 17 45,000.00 45,000.00 90,000.00 207,306.77 $ 117,306.77 95% 21708 Reconductor Feeder 16 20,000.00 25,000.00 45,000.00 445.89 $ (44,554.11) 0% 21709 Hutchinson High School 35,000.00 25,000.00 60,000.00 33,755.03 $ (26,244.97) 75% 21710 New Developments 50,000.00 - 50,000.00 27,384.44 $ (22,615.56) 80% 21711 Hutchinson High School 25,000.00 1,000.00 26,000.00 21,660.17 $ (4,339.83) 100% 21712 Transformer Replacements 40,000.00 10,000.00 50,000.00 - $ (50,000.00) 0% 21713 New Developments 50,000.00 - 50,000.00 5,023.72 $ (44,976.28) 80% 21714 Meters 30,000.00 - 30,000.00 6,685.08 $ (23,314.92) 20% $ 360,000.00 $ 178,500.00 $ 538,500.00 $ 407,742.65 $ (130,757.35) Work Order Description 51701 Vactron 51702 F550 Dump Truck 51703 F550 Super Duty Bucket Truck 51704 Tractor Backhow 51705 Lift Administrative Total Total Percentage Budgeted Actual Difference Completed 60,000.00 37,864.00 22,136.00 100% 30,000.00 - 30,000.00 0% 130,000.00 - 130,000.00 0% 60,000.00 61,827.19 (1,827.19) 100% 17,000.00 16,733.20 $ (266.80) 100% $ 297,000.00 $ 116,424.39 $ (180,575.61) Natural Gas Work Total Order Description Materials Labor Budgeted 61701 Transmission Lateral to HCP - ROW Easements $ 500,000.00 $ 3,000.00 $ 503,000.00 $ 61702 Transmission Lateral to HCP - Materials and Permits $ 500,000.00 $ 3,000.00 $ 503,000.00 $ 61703 Interconnect Station - Hanska 200,000.00 10,000.00 $ 210,000.00 61704 Misc Developments and Improvements 30,000.00 15,000.00 $ 45,000.00 61705 Specific Gravity Meter - Hutchinson 40,000.00 1,000.00 $ 41,000.00 61706 SCADA Equipment - Hanska 15,000.00 5,000.00 $ 20,000.00 61708 Regulator Station Improvements 15,000.00 3,000.00 $ 18,000.00 61709 Service Lines 55,000.00 20,000.00 $ 75,000.00 61710 Meters, Regulators, AMI Modules 70,000.00 3,500.00 $ 73,500.00 61711 Industrial Metering and Regulation 20,000.00 3,500.00 $ 23,500.00 61712 Gas Detection Equipment 5,000.00 - $ 5,000.00 HUTCHINSON UTILITIES COMMISSION�� Board Action Form �'Ylkll'M1'k� Agenda Item: Review Policies Presenter: Jeremy Carter Agenda Item Type: Time Requested (Minutes): 5 Review Policies Attachments: Yes BACKGROUND/EXPLANATION OF AGENDA 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. Automatic Bill Payment Plan ii. Required Clothing iii. Small Hand Tools iv. Safety Glasses BOARD ACTION REQUESTED: None Fiscal Impact: Included in current budget: Budget Change: PROJECT SECTION: Total Project Cost: Remaining Cost: Automatic Bill Payment Plan Customers may authorize automatic bill payment through ACH withdrawals from a checking/savings account, or with the use of a credit/debit card. These payments are withdrawn on the date the bill is due. To authorize the withdrawals or automatic payment, the customer must complete an Authorization for Automatic Payment form available at the HUC's business office or on the HUC website. The customerwill receive their monthly utility billing statement showing the payment amount to be withdrawn. The customer may contact the HUC Customer Service Department before the amount is withdrawn to dispute the billing or with any questions. The customer will have approximately 10 days to review their bill before the money is withdrawn. If a customer's payment is dishonored for two consecutive months, the customer will be removed from the automatic payment plan and so notified. A service charge of $30 will be assessed to the customer's account for each dishonored payment occurrence. NON-EXEMPT REQUIRED CLOTHING HUC will provide employees required uniforms and safety clothing at no cost to the employee. This clothing may differ by Department. See Staff Personnel for a list of the clothing HUC will provide to those employees. All clothing issued to employees by HUC may only be worn while the employee is on -duty for HUC. Failure to wear flame resistant clothing at the appropriate times is a violation of HUC policy and will subject the employee to discipline. NON-EXEMPT SMALL HAND TOOLS HUC shall furnish the hand tools specified by the Director or Manager as necessary to perform the employee's job duties. HUC will replace any small tools damaged or broken on the job. The damaged hand tool must be turned into the employee's Director or Manager. It is the responsibility of the employee to replace any missing hand tools. NON-EXEMPT SAFETY GLASSES Employees must pay for their own examination (health insurance will generally cover 100% of examination expense). Any supplier who can provide certificate that the glasses meet OSHA requirements may fill the prescription. It is recommended that employees fill their prescriptions at any optical department who accepts the Minnesota State Contract. Forms are available in the business office. HUTCHINSON UTILITIES COMMISSION�� Board Action Form �'Ylkll'M1'k� Agenda Item: Approve Policy Changes Presenter: Jeremy Carter Agenda Item Type: Time Requested (Minutes): 5 App Changes to Policies Attachments: Yes BACKGROUND/EXPLANATION OF AGENDA 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. Errors in Billing ii. Payment of Your Bill iii. Recognition Policy-Service Awards and Retirement Gifts BOARD ACTION REQUESTED: Approve Policy Changes Fiscal Impact: Included in current budget: Budget Change: PROJECT SECTION: Total Project Cost: Remaining Cost: Errors in Billing Overcharged customers accounts will be credited on the next statement or refunded on the# final billing. Undercharged customers accounts may be billed for any orrnrc RGt eXGeediRg GRe (1) year MR; the (late of RedGo a comecti n WHA eine y eur of the INIng emor occuTeince and may be billed on a separate invoice, with an explanation of charges. Payment of Your Bill Payments are due by the date sh�hewp n6cated on the statement. Payment Locations • HUCL& business office at 225 Michigan Street Southeast • Drop box at either Uhe HUC business office or Hutchinson City Center Payment Methods • Cash, check or money order • automated phone system at 855-820-2288 with VISA/MasterCard/Discover • automatic bank payment plan • online at www.hutchinsonutilities.com When paying in any manner other than cash, no change will be given. No second party or post-dated checks will be accepted -.4;, and checks will not be held. A dishonored payment is treated as a non-payment. If notification of the dishonored payment is received by HUC, the customer will be charged a $30 processing fee. For billing questions, c nr cr HUC customer service vlia e a alill at l,ii„! ,q„1�„� ! 1h. L,t (.ill „!I„n„s,q„n,,,,,r..r] n,,,,,,L, . NON-EXEMPT RECOGNITION POLICY — SERVICE AWARDS AND RETIREMENT GIFTS Objective Service awards and retirement gifts are provided to recognize and reward employees for service with the company. Awards are granted without regard to position or salary. Scope of Policy Full-time, active employees are eligible for a service award 1'o r every five (5) years of service completed. The service awards may increase in value based on longevity, per the table listed in Service Award Procedures below. Service Credit Service credit for service awards will count from the first day an individual is considered a full- time employee of HUC and continue while the employee remains on full-time, active status. If an individual has a break in service, their service credit may resume accumulating when they return to full-time status, depending on the nature of the break. Service Award Procedures HUC will inform the individual employee of their eligibility fl'or a ery � ce awar(l.. LH gN e enif, oyee and ask t4e ,,�er-e t4ey , „la like may s&ct a gift card fFem pe �n the aniouunt note(I on the table below. Employee will receive a Certificate of Appreciation signed by the General Manager and presented to them at the Recognition Banquet. Gift cards must be for personal, tangible property and may not be redeemed for cash. Amount Years of Service $50 5 Years $100 10 Years $125 15 Years $150 20 Years $175 25 Years $200 30 Years $250 35 Years $300 40 Years Retirement Recognition Procedures Retirees have the option of a potluck luncheon in their honor. A gift from HUC valued at no greater than $300 will be given to the retiree. The immediate supervisor will be responsible for coordinating the purchase of the gift. EXEMPT RECOGNITION POLICY - SERVICE AWARDS AND RETIREMENT GIFTS Objective Service awards and retirement gifts are provided to recognize and reward employees for service with the company. Awards are granted without regard to position or salary. Scone of Policy Full-time, active employees are eligible for a service award 1'o r every five (5) years of service completed. The service awards may increase in value based on longevity, per the table listed in Service Award Procedures below. Service Credit Service credit for service awards will count from the first day an individual is considered a full- time employee of HUC and continue while the employee remains on full-time, active status. If an individual has a break in service, their service credit may resume accumulating when they return to full-time status, depending on the nature of the break. Service Award Procedures HUC will inform the individual employee of their eligibility fl'or a erv�ce awar(l.. LHgNe enif, oyee and ask t4e ,,�et:e t4ey , „la like may s&ct a gift card 40ffl Pe �n t1le Mlouunt note(I on flic table below. Employee will receive a Certificate of Appreciation signed by the General Manager and presented to them at the Recognition Banquet. Gift cards must be for personal, tangible property and may not be redeemed for cash. Amount Years of Service $50 5 Years $100 10 Years $125 15 Years $150 20 Years $175 25 Years $200 30 Years $250 35 Years $300 40 Years Retirement Recognition Procedures Retirees have the option of a potluck luncheon in their honor. A gift from HUC valued at no greater than $300 will be given to the retiree. The immediate supervisor will be responsible for coordinating the purchase of the gift. HUTCHINSON UTILITIES COMMISSION Board Action Form &F,WK, MENEMENEMENEENUMEM Agenda Item: Resolution Authorizing City Council to issue 2017B Bonds and Redeem 2003B Bonds Presenter: Jeremy Carter Agenda Item Type: Time Requested (Minutes): 5 New Business Attachments: Yes BACKGROUND/EXPLANATION OF AGENDA ITEM: Part of the process of issuing bonds to finance the generator 6 & 7 project is for the Hutchinson Utilities Commission to approve a resolution finalizing the authorization process that will enable the Hutchinson City Council to receive bond bids the morning of October 10th, 2017. Based on competitive bids that are favorable, this resolution will concur with Hutchinson City Council approving a resolution and awarding the 2017B bond bid to the lowest bidder the evening of October 10th at a regularly scheduled council meeting. A prior resolution was approved by Hutchinson City Council on September 12th authorizing the Pre-Sale of bonds which allowed disclosure documents to be prepared for bond investors to review, a call to be scheduled with a rating agency, and bid proposals to be solicited. Based on awarding a bid on October 10th, the bond closing procedures and receiving of bond proceeds will occur around the last week of October/Early November. BOARD ACTION REQUESTED: Approve Resolution Authorizing the Sale of Bonds Fiscal Impact: Included in current budget: Budget Change: PROJECT SECTION: Total Project Cost: Remaining Cost: HUTCHINSON UTILITIES COMMISSION RESOLUTION RELATING TO PUBLIC UTILITY REVENUE BONDS, SERIES 201713; AUTHORIZING THE HUTCHINSON CITY COUNCIL TO PROVIDE FOR THE ISSUANCE AND SALE THEREOF BE IT RESOLVED by the Hutchinson Utilities Commission (the "Commission") as follows: 1. Recitals. To finance improvements to the electric generation and distribution system operated and managed by the Commission it is proposed that the City of Hutchinson (the "City") issue its Public Utility Revenue Bonds, Series 2017B, in the approximate principal amount of $17,455,000 ("the "Bonds"), the principal of and interest on which shall be payable from the net revenues of the electric generation and distribution system and natural gas system operated and managed by the Commission. The Bonds are to be issued pursuant to and secured by the covenants and agreements contained in a resolution to be adopted by the Hutchinson City Council on October 10, 2017, which resolution is attached hereto and is by reference incorporated herein (the "Resolution"). 2. Authorization and Concurrence. The Commission hereby finds and determines that the issuance of the Bonds is necessary and in the best interests of the Commission and authorizes the City to issue the Bonds as provided in the Resolution, and hereby joins in and adopts the Resolution, including all of the covenants and agreements therein contained with the same force and effect as if the Resolution had been adopted by the Commission. The Commission further approves the redemption of the City's Public Utility Revenue Bonds, Series 2003B, dated, as originally issued, as of March 1, 2003, currently outstanding in the principal amount of $590,000, as previously approved by the City. Adopted: September 27, 2017. ATTEST: Monty Morrow, President Mark Girard, Secretary HUTCHINSON UTILITIES COMMISSION�� Board Action Form �'Ylkll'M1'k� Agenda Item: Declaration of Surplus Equipment Presenter: Jeremy Carter Agenda Item Type: Time Requested (Minutes): 5 New Business Attachments: No BACKGROUND/EXPLANATION OF AGENDA ITEM: As part of HUC's Fleet Managment program staff is recommending the sale of the surplus fleet below. Equipment: 2002 Ford F550 Dump Truck 2005 Dodge Dakota 2006 Ford F550 Super Duty Bucket Truck BOARD ACTION REQUESTED: Approve sale of surplus equipment Fiscal Impact: $30-$40K in Sale proceeds Included in current budget: Yes Budget Change: PROJECT SECTION: Total Project Cost: Remaining Cost: