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Home My WebLink AboutPACKET Utilities Committee 2004-06-104 v, ca//2 t AGENDA TOWN OF ESTES PARK UTILITIES COMMITTEE June 10, 2004, 8:00 a.m. Preparation date: 6/4/04 *Revision date: ACTION ITEMS 1. 2004 Water Line Replacement Projects: â€¢ Request approval of the Upper Broadview and Devil's Gulch Water Line Design/Construction Management Scope by Cornerstone Engineering Note: Lori Jeffrey-Clark cannot attend this meeting due to a scheduling conflict. REPORTS Light and Power 1. Light and Power Financial Data 2. Light and Power Rate Study 3. MacGregor Avenue Underground Conductor Project 4. Fiber Optics Project 5. Christmas Decoration Project Water 6. Water Department Financial Data 7. Northern Colorado Water Conservancy District Snowpack Data - May 31 8. Water Department Raw Water Supply 9. Fall River Water Tank Project Note: The Utilities Committee reserves the right to consider other appropriate items not available at the time the agenda was prepared. TOWN OF ESTES PARK Inter-Office Memorandum Date: June 4,2004 TO: Utilities Committee FROM: Bill Linnane ~~ SUBJECT: Scope of Services - 1) Summer Line Replacement on Upper Broadview; 2) Service Line Replacement on Devils Gulch Road Â· Background: Every year by contract the Water Department turns on and off a summer line to the residents of Upper Broadview and a summer main on Devils Gulch Road. The line on Upper Broadview is above ground and creates maintenance problems associated with wintertime snowplowing operations, summertime road grading operations and is prone to damage from vehicle traffic. Pipeline size is inadequate by today's standards for the number of residences served, exposure to the elements and repeated turn on/offs creates pipeline deterioration. A replacement water main line will be required in Upper Broadview to service the number of residences. The Devils Gulch Road line requires more wintertime maintenance in order to keep the line from freezing. This line supplies water to one residence only and is larger in size than is required by today's standards. A 1-inch service line is required for the Devils Gulch Road replacement. Budget: Cornerstone Engineering: Scope of Services Water Main - Upper Broadview Design/Bid: $6,296.00 Construction Observation : $3,368.00 Total: $9,664.00 Action: Staff recommends approval of the Scope of Services from Cornerstone Engineering for the design of a water main replacement on Upper Broadview, with construction bids to be returned to the August Utilities Committee and approval to use same contractor for the service line replacement on Devils Gulch Road. BG/lb Attachment T d \ '1 7 T 4--f Acl [*1 r O cl \00 - 6900 0 R, 9 -ki l Â¥0= 0 O P O 09 0 KI m I m . S ry 0. 0 4 4 <Jo C 1 -49 0/ 00 0 0 0 0 o~/1 2 Â°j Joi Joi u e 9 t 1-----_122)AID~, d 0. 1 0 0.0 0 0 G, 4 0 j// 0 0 -96-71-aiEE- f o 0 0 9-4 1 1 -~r,WÂ«~>co 51 2 o 04 0 L 0 0/ 0 - it 1 ppEARRAD~W-2~ Â° '~ 0 00 0 00 0 0 0 04-}.4~:~- - 0 0 0 CP 0 0 0 go j----21-J' 83~Â£2.2b. - j 0 0 9 Proposed Main . / a 7- line location TZ & 4 9 /% 0 - PI~ .f-- <g ~ -4~~ 40 i g f / ~ |4' ~ Ck, ~ 8 1 qsikinglÂ»,~C 0 0 1Â«30 < 00 0 4 0 ANT LRACK aug 9 0 11(0 C 0 Q Id=, 4 i || 0 19 -d 11 I f--1 b 9l l -0 n 4091 t=~ iO 0 L IO 00 000 - 9 6 - 0 0 13 Proposed servic X~ line location 0 0 1 0 Ei,sling*8 0 location 0 0 0 1 /1 7 NOOn/LN -11 00 1~'b /'jv/----h,ul#*7 1 .) 1 V n. i Â¢j- 1 " ft Fittin'e Ii}i.proue.111217.-ts The existing $9.614 capital improvements have reduced the Water Department cash fund to the point where a $1.6M catastrophic fund can be- maintained. In addition, approximately $400,000/yr. can be spent on facilities and pipeline maintenance 1 without operating with a negative cash flow. The Town of Estes Park and a majority of the water industry uses the following system to prioril-ize annual pipeline projects: Priority #1: Extremely high maintenance lines Priority #2: Extremely low pressure domestic use and <500 GPM fire protection lines , Priority #3: <500 Gl?M fire protection lines Category 1 has been established as the 1/1 priority so that water line breaks that cause extremely long water service delays can be eliminated. These high maintenance lines also result in inadequate fire protection and extreme damage to ; private and public land. Category 2 has been set as the next priority so that lines that are not immediately in danger of breaking, but experience ]Ow pressure and inadequate domestic and fire protection service, can be eliminated. Category 3 contains only fire pro tection problems, therefore, it has been established v as a third priority. All 3,categories are very important, but projects must be prioritized in such a niethocl*as that described.. The following is the Current annual improvement lists with associated projected costs, categorized as previously exblained. Brn m A-'râ‚¬D 57- A-v en 9 d ~~~ -0 ATE PrioritY #1: Extremely High Maintenance Lines LF +/- Amount C OvM P LeTE. Beaver Point to Ramshorn Village 1,900 $135,000. 47-1 QLCTS Big Horn 8" 1,400 95,000 Covq pceTE Big Thompson 10" 3,300 230,000 Co .4 NerE- Chapin/Chiquita 2" 500 35,000 CO-1 ~Lâ‚¬*19 Chiquita 2" 800 52,000 ts#lpierâ‚¬ Fall River Corridor Abandonment 4,000 305,000 2.eon MacGregor Ave. E./Wonderview 2,700 190,000 d.<9 Al~LOE MacGregor Ave. W./Wonderview 3,900 270,000 CLowlF-Â·32Â¥-â‚¬ Stanley Circle 2" 500 35,000 Subloto/ $1,347,000 Priority #2: Extremely Low Pressure Domestic Use and <500 GPM Fire Protection 100+ uee.Or Gr,ox*,604: 'f"lu 29.zi,14â€¢â‚¬uiwe-7 tuoufc, *O-6 eri or,4 3; 1,1.00 Po 000 9/2/3 E 9 < 100 z. Country Club 2" 1,200 $8d,000 â‚¬ C.ompLOrâ‚¬ Devils Gulch East-Phase I 4,300 300,000 ' 'â‚¬ 2 ott Devils Gulch West- Phase Il 2,100 150,000 5Â»4â‚¬ 2 0 02 Evergreen 4" 1,400 100,000 log Fall River Tank #2 (Master Plan) 4,300 300,000 0,â‚¬. ca w-1 pLerb [HWy. 7 to Prospect Mountain Pump Hou:e 2,900 205,000 ,.tiC.ov,lf l_lgr-â‚¬~t\Inrth Lane to Devils Gulch 1,200 80,000 Â·*2&08.'Panorama Circle 3,100 216,000 'Afler-480uthern Interconnect 900 60,000 4Â¢.*10.08 11-Un Drive 2" 60'0 , 4*306 ' $1,536,000 Subtotal k \-1.<,Jv '31 MA#-4 0.,4 pu.i , t.-4~=tdo Â·.tridbicÂ£. 64â€¢ 4,%,0 Prt ?.9.13Â¥'PE. lili A-Â«-500-rt-\20.,h 1,1 T-01(.04 hlirrY- 'pr,-2Jct_T , Con-AduleD L-"2 (DR.â‚¬413Â£--e . 4-3 . 1 Priority #3: <500 GPM Fire Protection Feet Amount MATÂ¢D List Â·,-Â·fl.v Â£-n U â‚¬T Axminster Lane 2,000 $120,000 Belleview Heights 2,000 120,000 Broadview/Lower Broadview 54,000 325,000 Brook Drive 1,200 70,000 Cedar Lane 1,500 90,000 Charles Heights Water Main 2,000 110,000 800 50,000 11 4 (lemorrah Drive Davis Hill 3,000 180,000 200 W Eagle Cliff 2,500 150,000 East Lane/North Lane 3,000 180,000 Fort Morgan Colony 1,000 60,000 1-lili Road 2" 1,500 90,000 Zoos HilIStreets 5,000 300,000 Hondius Heights 5,500 335,000 1,000 60,000 1.DOE Juniper Lane Lone Pine Acres 3,500 210,000 Narcissus Circle . 1,000 60,000 ZOO b Old Mocassin Drive 1,000 60,000 Old Ranger Road 900 55,000 500 30,000 zook Park View Lane Pinewood Lane 1,500 90,000 26Â°+ Spruce Drive 500 30,000 Sunny Acres 1,000 60,000 Tranquil Lane i 500 30,000 1.800 105,000 Upper Broadview lu.oy; 44 4)1408'Â¥ 40% : r:e.câ‚¬4+ '500 30,000 2 P 10 04 Webb Collages Agk .â€¢lat. tew.lâ‚¬ bee 5,Sure_ 1,900 60,000 Willow Lane ex, bl*4 Sublotal <ij:jÂ·~ $3,060,000 C.O .1 1-1,1 UED (b a..91 TOTAL $5,943,000 By comparing the esliInated project cost-5 with the available funds of $400,000 +/- per year, it is obvious that the funds available are short of the project costs. 744 05 -3.1- Vt, ,_D C>Al ALDS Tb C.4-11-~Ov'- C nÂ·J 2. G k b:731 Â©10,3 2.006 -1-kli A DR-,~LoAGS DA, -1-11 ; 6 4 400 l' , 00 000 7-00 L Po Al> aruâ€¢ LA- A JE 8 Electric Financials.xls 6/8/2004 LIGHT AND POWER FUND 2003 VS. 2004 MONTH-TO-DATE CASH FLOW COMPARISON MAY MAY 2003 2004 Difference Revenues Utility Sales $ 639,385 $ 687,149 $ 47,764 Other 34,380 33,194 (1,186) Total Revenues $ 673,764 $ 720,343 $ 46,579 Expenditures Operation and Maintenance Expense Source of Supply $ 289,350 $ 276,653 $ (12,697) Distribution and Maintenance 136,418 96,742 (39,676) Customer Billing and Accounts 57,669 47,416 (10,253) Administration and General 84,946 86,786 1,840 Transfer to Vehicle Fund 2,617 4,240 1,624 Total Operation and Maintenance Expense $ 571,000 $ 511,838 $ (59,162) Debt Service 24,917 25,170 254 Capital 337,902 19,525 (318,377) Transfers to General Fund and Museum 59,573 72,322 12,749 Total Expenditures $ 993,391 628,855 $ (364,536) Total Surplus (Deficiency) $ (319,627) $ 91,488 $ 411,115 Note 1) Transfer and debt service are annual amounts accrued on a monthly basis. R L&P 1 Electric Financials.xls 6/8/2004 LIGHT AND POWER FUND 2003 VS. 2004 YEAR-TO-DATE CASH FLOW COMPARISON YTD YTD May May 2003 2004 Difference Revenues Utility Sales $ 3,402,247 $ 3,751,224 $ 348,977 Other 183,189 135,014 (48,175) Total Revenues $ 3,585,436 $ 3,886,237 $ 300,801 Expenditures Operation and Maintenance Expense Source of Supply $ 1,694,128 $ 1,797,422 $ 103,294 Distribution and Maintenance 509,222 574,446 65,223 Customer Billing and Accounts 271,321 279,918 8,597 Administration and General 437,556 474,803 37,246 Transfer to Vehicle Fund 13,083 21,201 8,118 Total Operation and Maintenance Expense 2,925,310 3,147,789 $ 222,479 Debt Service 124,583 125,852 1,269 Capital 559,789 55,636 (504,154) Transfers to General Fund and Museum 297,863 361,610 63,746 Total Expenditures $3,907,546 $3,690,887 $ (216,660) Total Surplus (Deficiency) $ (322,110) $ 195,351 $ 517,461 Note 1) Transfer and debt service are annual amounts accrued on a monthly basis. R L&P 2 Electric Financials.xls 6/8/2004 LIGHT AND POWER FUND 2004 TOTAL BUDGET VS. ACTUAL YTD CASH FLOW ANALYSIS YTD Budget May YTD % of Target 2004 2004 Budget % Revenues Utility Sales $ 8,868,949 $ 3,751,224 42% 43% Other 391,835 135,014 34% 42% Total Revenues $ 9,260,784 $ 3,886,237 42% 43% Expenditures Operation and Maintenance Expense Source of Supply $ 4,440,000 $ 1,797,422 40% 42% Distribution and Maintenance 1,580,649 574,446 36% 42% Customer Billing and Accounts 713,137 279,918 39% 42% Administration and General 1,206,092 474,803 39% 42% Transfer to Vehicle Fund 50,883 21,201 42% 42% Total Operation and Maintenance Expense $ 7,990,761 $ 3,147,789 39% 42% Debt Service 302,045 125,852 42% 42% Transfers to General Fund and Museum 867,863 361,610 42% 42% Capital 735,254 55,636 8% 42% Total expenditures $ 9,895,923 $ 3,690,887 37% 42% Note 1) Charge for Services and Source of Supply target % based on historical data. R L&P 3 1 6 - I ./ Â¥ A I . i i %61 t.4 6 1 4 6 . r 6 . 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I . 10,000,000 8,000,000 - 1 .--* -- I . -I . r 6,000,000 --- ~ O Budget - 4,000,000 - _ _ - _ I Actual 2,000,000 -= -*W.y.-- ts>O.. 711 2<8 3.-, 2202,2 , I 2004 Year-to-Date PRPA Invoices vs. Budget ~ . 4, I . 5,000,000 4,000,000 -- .. 3,000,000 O Budget 2,000,000 -- _ _ __ __Â· I Actual 1,000,000 - 4 1-ift~~____~_ 6 0 .1.0 4 : 4 3 23. 8 & a a i. 1 1 1 1 1 i 1 1 1 g2j<J R L&P-11 9, TOWN OF ESTES PARK Inter-Office Memorandum June 3,2004 To: Mayor John Baudek From: Bill Linnane CC: Rich Widmer Pete Brandjord Subject: Questions about the Town's Electrical Rate System and the Options Available to Our Customers Notes: 1) Please refer to the attached rate options sheet. 2) Demand: The highest electric load average kW drawn in a 15-consecutive-minute period each billing cycle. The rate is $7.89/kW. 3) Out ofthefour residentiat rates, the #1 Residential Rate and #4 Residential Demand Rate do not provide an incentive to limit usage during Plane River Power Authority's demand times (winter). During the Rate Study process this year, staff will ask Black and Veatch to review the possibility of "sunsetting" these two rates. 4) The meter differences and associated meter costs to switch the 7,100 #1 Residential Rate customers and the 400 #4 Demand Rate customers to another rate make the changes economically unrealistic. A compromise would be to allow no new customers in these rate classes. Ouestion #1: What is the dijference between the different residential rate categories? Answer #1: There are four rate options for residential users and our customers can be categorized into two classes: Class A - Electric Heat customers and Class B - Non-electric Heat customers. Class A - Electric Heat All customers of this class qualify for Rate #2 (Basic) and Rate 4 (Demand). If usage will be less than 25,000 kWh/yr. they also qualify for Rate #1 (Residential) and if they own a thermal storage unit, they qualify for Rate #3 (Residential Time-of-Day). Rate #1: Residential Rate - Electric heat customers qualify for this rate if their annual usage is less than 25,000 kWh/yr. This rate may be the most economical for a typical, energy- efficient 1,500 sq.-ft. home or condominium when: 1) energy use is in the 500-1,000 kWh range/mo. 2) demand is in the 4-6 kW range which would be equal to a: Electric heat: 4 kW Electric stove: 1.5 kW Misc. electric: .5 kW 6 kW - 15 minute demand R2-L&Pl Energy Rate Demand Rate .07203/kWh None Rate #2: Energy Time-of-Day (Thermal Storage Unit Customer) A thermal storage unit stores energy (heat) in the off-peak hours as set with a time clock, and the thermal mass releases the heat during the peak or demand hours. Additional information about these heaters is available through handouts or by calling the Public Works Department at 577-3580,577-3582,577-3583 or 577-3588. Energy Dernand Winter/Summer 0.8760 kWh .03100 (other times) WA Rate #3 Residential Basic Time-of-Day Rate. Platter River Power Authority charges Estes Park a relatively high power cost during its peak generation period each month. That period in the winter coincides with Estes Park's peak: 4-7 p.m. winter weekdays. In summer there is no correlation since PRPA's peak period is 2-4 p.m. and Estes Park's is 7-9 p.m... This rate is beneficial if the customer can limit usage during the 4-7 p.m. weekday times. A different energy rate is charged accordingly: Energy Energy Dernand Winter: 0.08643/kWh (4 - 7 p.m. weekdays) 0.06843 (other) N/A Summer: 0.07203/kWh Rate #4 Residential Demand Rate. In addition to an energy rate, a demand charge is also applied. This helps offset the PRPA raw power demand rate charged to Estes Park. In the winter, the demand periods of PRPA and Estes Park approximately coincide. They do not coincide in the summer, thus there is no demand rate in the summer. Energy Dernand Winter: 0.03663/kWh 7.89/kW Summer: 0.07203/kWh WA Class B - Non-electric Heat Only Rate #1, Residential Rate and Rate #3, Basic Time-of Day-Rate, will be economically beneficial to this class. Rate #1: Residential Rate 1) This rate has been established basically for non-electric heat customers due to their relatively flat power vs. time-of-use curve. Therefore, one flat energy fee is charged. A drawback to this fee is that it does not provide incentive to reduce demand period consumption. 2) Probably the most economical rate for this class customer. 3) Electric heat customers qualify for this rate if usage is less than 25,000 kWh/yr. 4) One energy rate - no Demand Rate - No Time-of-Day Rate Energy Rate Demand Rate .07203/kWh None R2-L&P2 Rate #3: Residential Basic Time-of-Day Rate. The Platter River Power Authority demand period in the winter coincides with the highest demand times in Estes Park: 4-7 p.m. winter weekdays. In summer there is no correlation since PRPA demand time is 2-4 p.m. and Estes Park's is 7-9 p.m.. This rate is beneficial if the customer can limit usage during the 4-7 p.m. weekday times. Energy Energy Demand Winter: 0.08643/kWh (4 - 7 p.m. weekdays) 0.06843 (other) N/A Summer: 0.07203/kWh Ouestion #2: Why would a customer not just pick the category with the lowest cost per kWh rather than the Category I Residential? Answer #2: - A new homeowner comes into our offices and says, "I would like electric service. What are my options?" - Given a customer's heat source, staff would recommend one of the four rates available: 1) Residential: All non-electric heat residential customers qualify for this rate. Customers with electric heat qualify for this rate if their annual electric usage is less than 25,000 kWh. Light and Power personnel check annually to assure electric heat customers on this rate do not exceed 25,000 kWh. 2) Residential Energy Time-of-Day: The customer can purchase a thermal storage unit and use this rate whether using either electric or non-electric heat. Light and Power personnel verify that the customer has installed a thermal storage unit prior to customer sign-up. 3) Residential Energy Basic Time-of-Day: This rate is available for all customers (electric or non-electric heat). Non-electric users may find this rate less expensive than Rate #1, particularly if they can limit their wintertime electric use between the hours of 4 and 7 p.m. on weekdays. 4) Residential Demand: This rate is for electric heat customers as it will not benefit non-electric heat customers. An electric zone controller (approximately $3,000+) will probably be needed to make the rate economical since the controller will minimize the electric load during the demand period. Rate #3 will probably be the most economical if a controller is not installed. â€¢ Which rate the customer chooses is dependent upon the rate structures listed on pages 1 and 2. Please see the available options per user class as discussed on pages 1 and 2 (Question #1). BL/lb Attachment R2-L&P3 Town of Estes Park Residential Electric Rate Options < Effective 1/1/2004 #1 Residential Rate 7,132 customers Monthly Customer charge $4.00 per month riA#Mil:firfa~/) Monthly Energy charge $0.07203 per kWh This is our standard rate for residential customers. Over 90% of our residential customers receive service at this rate. Customers with electric heat may receive service at this rate provided their annual consumption does not exceed 25,000 kWh. Electric Heat Rates #2 Residential Time-of-Day Energy Rate 210 customers Monthly Customer Charge $5.00 Monthly On-Peak Energy Charge $0.0876 per kWh Monthly Off-Peak Energy Charge $0.0310 per kWh This rate is available to all residential customers with electric thermal storage heating systems. On- peak hours are 6 a.m. to 1 p.m. and 3 to 10 p.m. weekdays. All other hours during the week are considered off-peak. All hours on the following holidays are considered off-peak: January 1St, Memorial Day, July 4th, Labor Day, Thanksgiving Day, Christmas Eve and Christmas Day. #3 Residential Basic Time-of-Day Energy Rate 5 custonners Monthly Customer Charge $5.00 Monthly On-Peak Energy Charge $0.08643 per kWh (September through April) Monthly Off-Peak Energy Charge $0.06843 per kWh (September through April) This is a new rate available to all residential customers. On-peak hours are 4 to 7 p.m. weekdays. All other hours during the week are considered off-peak. All hours on the following holidays are considered off-peak: January Ist, Labor Day, Thanksgiving Day, Christmas Eve and Christmas Day During the months May through August on-peak and off-peak hours are billed at the Residential Rate energy charge. #4 Residential Demand Rate 441 customers Monthly Customer Charge $5.00 Monthly Energy charge $0.03663 per kWh (September through April) Monthly Demand charge $7.89 per kW (September through April) This rate is available to all residential customers, but is most economical for customers with electric baseboard heat or radiant ceiling heat and have a demand controller installed in the residence. Monthly demand is the highest 15-minute average electric load occurring each month. During the months May through August energy consumption is billed at the Residential Rate energy charge and there is no demand charge. Note: All Energy charges will be increased by the 2004 Purchased Power Rider amount of $0.00137 per kWh to reflect the 2004 wholesale rate increase from Platte River Power Authority. R2-L&P4 Water Financials.xls 6/8/2004 WATER FUND 2003 VS. 2004 MONTH-TO-DATE CASH FLOW COMPARISON MAY MAY 2003 2004 Difference Revenues Water Sales $ 134,529 $ 176,392 $ 41,863 Plant Development Tap Fees 19,702 7,360 (12,342) Water Rights Tap Fees 34,320 21,933 (12,388) Other 12,752 2,153 (10,599) Total Revenues $ 201,304 $ 207,838 $ 6,534 Expenditures Operation and Maintenance Expense Source of Supply $ 150 $ - $ (150) Purification 43,407 32,309 (11,098) Distribution and Maintenance 48,807 45,146 (3,662) Customer Billing and Accounts 10,580 31,433 20,852 Administration and General 51,394 40,148 (11,246) Transfer to Vehicle Fund 396 1,167 771 Total Operation and Maintenance Expense $ 154,735 $ 150,203 $ (4,532) Debt Service 25,348 24,492 (857) Capital 94,631 11,785 (82,847) Transfer to General Fund 6,199 6,199 Total Expenditures $ 274,714 $ 192,678 $ (82,037) Monthly Surplus (Deficiency) $ (73,410) $ 15,160 $ 88,570 Note 1) Transfer and debt service are annual amounts accrued on a monthly basis. RW1 Water Financials.xls 6/8/2004 WATER FUND 2003 VS. 2004 YEAR-TO-DATE CASH FLOW COMPARISON YTD YTD May May 2003 2004 Difference Revenues Water Sales $ 644,467 $ 747,051 $ 102,584 Plant Development Tap Fees 137,943 61,614 (76,329) Water Rights Tap Fees 170,125 161,433 (8,693) Other 73,101 21,079 (52,022) Total Revenues $ 1,025,635 $ 991,176 $ (34,460) Expenditures Operation and Maintenance Expense Source of Supply $ 75,769 $ 98,057 $ 22,288 Purification 184,548 172,589 (11,959) Distribution and Maintenance 221,551 215,179 (6,372) Customer Billing and Accounts 51,140 89,582 38,442 Administration and General 286,935 248,511 (38,424) Transfer to Vehicle Fund 1,979 5,833 3,854 Total Operation and Maintenance Expense $ 821,922 $ 829,751 $ 7,829 Debt Service 126,740 122,458 (4,283) Capital 717,218 51,523 (665,695) Transfer to General Fund 30,995 30,995 Total Expenditures $ 1,665,880 $ 1,034,726 $ (631,154) Annual Surplus (Deficiency) $ (640,245) $ (43,550) $ 596,694 Note 1) Transfer and debt service are annual amounts accrued on a monthly basis. RW2 Water Financials.xls 6/8/2004 WATER FUND 2004 TOTAL BUDGET VS. ACTUAL YTD CASH FLOW ANALYSIS YTD Budget May YTD % of Target 2004 2004 Budget % Revenues Water Sales $ 2,047,000 $ 747,051 36% 31% Plant Development Tap Fees 200,000 61,614 31% 31% Water Rights Tap Fees 300,000 161,433 54% 31% Other 100,842 21,079 21% 31% Total Revenues $ 2,647,842 $ 991,176 37% 31% Expenditures Operation and Maintenance Expense Source of Supply $ 130,000 $ 98,057 75% 90% Purification 411,825 172,589 42% 42% Distribution and Maintenance 499,592 215,179 43% 42% Customer Billing and Accounts 219,647 89,582 41% 42% Administration and General 640,874 248,511 39% 42% Transfer to Vehicle Fund 14,000 5,833 42% 42% Total Operation and Maintenance Expense $ 1,915,938 $ 829,751 43% __242% Debt Service 293,898 122,458 42% 42% Capital 1,166,020 51,523 4% 42% Transfer to General Fund 74,387 30,995 42% 42% Total Expenditures $ 3,450,243 $ 1,034,726 30% 42% Note 1) Charge for Services target based on previous years data. Note 2) Source of Supply target based on previous years NCWCD invoices. Note 3) All other targets based on % of Year complete. RW3 40!1011!10100111111". N/#,f/,40#81,"10,#11'h N 1///11////1/11 11/1/01/2/1/#â€¢ - \1_LL# ##I##########*****il* ~*7**eeÂ©eeÂ©eemp \ 4,1,11,11,111,1,0/1,11,1. AÂ»Â»ilihill'illixÂ»Â»ar -\111/1,101,0,1,0,11,4 Â»NeÂ©Â©OX~NeÂ©NÂ«ON \011,11,1111,1111111'. 1 - KÂ©eNÂ©ONÂ©*00006Â»Â»6 40*2111#0â€¢##1///#11. Â©~4*00Â¢4NeÂ»Â»Nee,NÂ« l V:f ' .r##ff'f/#12""a//4~~/4- 0 1 1 1 1 Sales.xls 6/7/2004 - 02002 Â£0010 --- - - 000'0910 *001 0 Dea AON loO deS Snv Inf unr XeIN Jdv Jel/\1 qe=1 uer Water Sales by Month 9Mhl 300,000 250,000 - - 200,000 - --000'OOL --000'09 1 \45"1Â¥*000$#/1/#ill/*SS#*5*******fl##55* re//mill//0/imi'll"IN#'ll/'//i"//:~01# 1 i - 1 1 , j - \##,2,7,/,22*-''f'fih U AixÂ»xÂ«<Â»XÂ«> gg CNN bâ‚¬ 0 tb> 00 01- <30<>,Â»XÂ»xx (N > 95,00*,00. r*X & Vt'.4 k Dea AON PO deS 6nv Inr unr XeIN idv qe=1 F-12002 1 12003 L--3 2004 -Budget i.1.1 4. Snowpack and Streamflow Comparisons May 1 st, 2004 - Snow Water Content % of Average Colorado's Statewide Snowpack 1 70% Upper Colorado River (1) 50% South Platte Tributaries (2) 67% Snow-Water Content Comparisons (inches} May 1st, 2004 May 1 Comparative Snow-Water Content Snow-Water Content Watershed 2004 Average 1 % Avg 2003 2002 2001 2000 Blue River 8.4 12.9 65% 16.0 4.0 10.7 11.8 Upper Colorado River 3.7 11.2 33% 12.6 2.3 5.9 8.4 Willow Creek 3.8 7.1 54% 11.2 2.0 53 7.9 Fraser River 5.8 11.9 49% 15.5 3.1 10.4 11.4 Poudre River 7.7 13.1 59% 14.9 5.6 9.5 11.8 Big Thompson River 10.7 14.9 72% 16.4 5.3 11.1 12.9 St. Vrain River 7.1 9.7 73% 11.2 2.2 6.0 9.5 Boulder Creek 7.7 11.5 67% 14.3 1.5 7.3 6.6 Agr-Jul Maximum. Minimum and Most Probable Streamflow Forecasts (1000 afl Forecast Most Forecast Aprdul Most Prob Watershed Minimum Probable Maximum Average % Average Blue River 177 200 223 275 73% Upper Colorado River 104 120 136 220 55% Willow Creek 25 30 35 48 62% Fraser River 62 71 80 113 63% Poudre River 95 120 145 227 53% Big Thompson River 60 70 80 94 75% St. Vrain River 51 61 71 91 67% Boulder Creek 28 33 38 51 65% South Platte Tributaries 12341 284 1 334 1 463 ~ Precipitation Totals Average 1 % Average ApMI 1.55 0% November-April 2.70 0% (1) Includes the Colorado, Willow Creek, Fraser and Blue River Watersheds (2) Includes the Poudre, Big Thompson, Saint Vrain and Boulder Creek Watersheds http:/twww. ncwcd.org/data&reports/snowpacldsnowpack. pdf