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Home My WebLink AboutPACKET Light and Power 1993-10-07:4 1 AGENDA Light and Power Committee October 7, 1993 10:00 a.m., Board Room 1. U.S. West-Phil Vasquez, Don Gifcia o Construction Program / for Estes Park Area 2. 1993 Electric Rate Study-Max Kiburz o Final Study Presentation o Recommended Rate Changes 3. Prospect Mountain - Proposed Lease Agreement 4. Reports A. Financial Report B. Project Updates o Current Transformer Metering Test Program Billing Adjustments o Hand Held Meter Reading Implementation C. Platte River Power Authority NOTE: The Light and Power Committee reserves the right to consider other appropriate items not available at the time the agenda was prepared. I . I ' - 2 2 U .2 11*0Â·50 2 N E 12 2; 5, A. % 1 * * a. 0 000 O a.) 1- 00 43-0 - 32 i -2 -E -E g -3 -2 -2 Â» E -2 t.@ E--2 ellt =1. h a.c k -8 RE u,a,Ac#ES- .,4 =W 8 a'M , r 4 5 4 - 40) -C A Z . 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SERVICE REQUESTS PENDING NEW SERVICE 36 ADDITIONAL SERVICE 28 REGRADES 126 TOTAL ORDERS PENDING 190 SERVICE REQUESTS COMPLETED NEW SERVICE 95 ADDITIONAL SERVICE 23 REGRADES 35 TOTAL ORDERS RELEASED 153 4 CAPITAL SPENDING 1993 SPECIFIC PROJECTS 3227H50 $498,600 ~7 /4,Â» 3227H55 230,100 2* d<,6Â£~ ROUTINE SPENDING 419,200 1 f 9.tuu. PROPOSED 1993 SPENDING $1,147,900 r. k PROPOSED CAPITAL SPENDING 1994 t r lt\~- SPECIFIC PROJECTS //719}93. 3127G07 $4,853,200 - 3/ -71 )Â·/Â»'Ed 6Â«2 3127G06 5,700,000-50 04 071 7 /7 (34 JfÂ» 'lu,+ rh L U .(/1...A ROUTINE SPENDING 500,000 PROPOSED 1994 SPENDING $11,053,200 TOWN OF ESTES PARK October 6, 1993 OFFICE MEMORANDUM TO: Light and Power Committee FROM: Richard E. Matzke-72-07Â» SUBJECT: 1993 Electric Rate Study Recommended Rate Changes Attached is a copy of the 1993 Electric Rate Study for the Town of Estes Park performed by M.E. Kiburz and Associates of Boulder, CO. The main purpose of the study was to update the Town's retail rates, set in 1991, to incorporate the Platte River Wholesale rate change. Following is a summary of recent Platte River wholesale rates to the Town: Demand (per kW) Energy (per kWh) pre April 1992 $10.40* $0.0132 April 1992 to March 1993 11.01* 0.014 April 1993 to present 10.78** 0.014 * Based on Town's system peak demand ** Based on Town's load at time on Platte River's system peak demand. One finding of the rate study was that the purchase power rider, which is indexed to energy consumption, tends to undercompensate rate classes which have no demand charge, for the wholesale rate change which involved a change in billing demand computation. On the other hand, the purchase power rider overcompensates rates which do have demand charges. EXISTING RATES . Also attached is a summary comparison of the Town's existing electric rates and the proposed revisions. The study recommends a decrease for the Residential, Small Commercial, and Municipal energy rates. The study recommends a small increase in the winter season demand charge and energy charge for the Residential Demand rate, but a significant reduction in the summer season demand charge. For the Large Commercial rate, a slight increase in the energy charge and a decrease in the demand charge is recommended. Also the study recommends eliminating the minimum demand ratchet for most Large Commercial customers, but reserving the right to impose a 60% minimum demand charge by season for a customer which 2-1 . . 1 peaks only in a month coincident with Platte River's seasonal peak load. Following the rate comparison is a comparison of rate change *impacts on "typical" monthly electric bills. TIME OF DAY RATES Another purpose of the study was to determine the effect of Platte River's seasonal coincident peak billing on the Town's time of day rates. The study determined that is now appropriate to include weekends and certain holidays in the off peak period. The study recommends a slight increase in the on peak energy charge and a slight decrease in the off peak energy charge for the Residential Time of Day Rate. A small increase in the on peak energy charge is recommended for the Large Commercial Time of Day Rate. The study recommends elimination of the off peak demand charge for both time of day rates. NEW RATES The study also includes a recommended Outdoor Area Lighting Rate, a Residential Time of Day Energy Rate and a Small Commercial Time of Day Energy Rate. PURCHASE POWER RIDER The Purchase Power Rider, which allows the Town to pass through wholesale rate changes to all rate classes will now be based on the Platte River rate in effect since April 1993. The amount of the purchase power rider will be zero until our wholesale rate from Platte River changes. The Light and Power Department recommends that the rate changes included in the 1993 Electric Rate Study be forwarded to the Town Board of Trustees for consideration at a public hearing to be held at the regular Town Board meeting on November 23, 1993. REM 2-2 1993 Electric Rate Study Proposed Changes EXISTING* PROPOSED Residential Energy GB/kWh) $0.06501 $0.06359 Residential Demand Energy ($/kWh) 0.03 0.03085 Demand-Summer ($/kW) 5.00 3.93 Demand-Winter ($/kW) 7.00 7.15 Residential-TOD Energy (On peak) ($/kWh) 0.03 0.03085 Energy (Off peak) ($/kWh) 0.0255 0.025 Demand (Off peak Differential) ($/kW) 3.50 Eliminated Small Commercial Energy ($/kWh) 0.07044 0.06892 Large Commercial Energy ($/kWh) 0.02875 0.02959 Demand ($/kW) 9.65 9.26 Large Commercial-TOD Energy (On peak) ($/kWh) 0.02875 0.02959 Demand (Off peak Differential) ($/kW) 5.35 Eliminated Municipal Energy ($/kWh) 0.06298 0.06216 Note: No change to customer charge in any rate class. *All energy rates are reduced by $0.00118 per kWh Purchase Power Rider. REM October 6, 1993 2-3 1993 Electric Rate Study New Rate Schedules Residential Energy-TOD Customer Charge $3.00 Winter Season Energy (On peak) ($/kWh) 0.08 ' Energy (Off peak) ($/kWh) 0.025 Summer Season Energy ($/kWh) 0.06359 ' Small Commercial-TOD Customer Charge 7.25 Winter Season Energy (On peak) ($/kWh) 0.0867 Energy (Off peak) ($/kWh) 0.025 Summer Season 0.06892 Energy ($/kWh) Outdoor Area Lighting Monthly Rate 5.25 REM 2-4 October 5, 1993 O 91- m O C) 91Â· ~ Â®NOâ€¢-4-N CD CO co (D 1~ Lf) 000000 000000 32 2 39 0 32 32 4 4- 0 4- co to co M Lo to O 91- 0 ~Â£ 60046#N =4-000- - - 0 0 4- 4 4 6 4 4 1354/ 65 c) 09 h co CO co C)â€¢-C)C)(NI 52 09 4 6 N .-- mÂ©moc) r- r- 0 9 ,-hh<0004- ,-N MOCD 10 N 14 4 MANOW NNâ€¢--NO r-N M-LO coN ocÂ·ic; 09 2 ah(NOC)4Â· 0) - r r- 4. 53 <U,C)=<g I Z Z O 9 z h 00 # EE -1 22 WLU I 0 0 B OLD 00 h â€¢- -1 << M LOONCON < Ir -(N.-,- 9 00 O- m oc DJ 0- 0- U.1 2-5 10/7/93 Â· IN3kl MONTHLY MONT 1991 Ap AVERAGE AVERAGE AVERAGE RATE RATE INCREASE $/1<WH ($) LARGE COMMERCIAL 27593 1 1416.9 1446.1 29.22 E CHANGE IMPACT COMPARISON -0.00118 ESTES PARK LIGHT AND POWER DEPARTMENT RESIDENTIAL 4.75 RIDER (12/93) SMALL COMMERCIAL TYPBILL.XLS RES DEMAND SUMM RES DEMAND WINTER 1. RES DEMAND TOTAL ELECTRIC RATE STUDY TOWN OF ESTES PARK, COLORADO Light and Power Department M. E. Kiburz and Associates October, 1993 1 M. E. Kiburz and Associates Consulting Engineers 443 Sugarloaf Mtn Rd Boulder, Colorado 80302-9639 (303)442-6450 Telecopy (303) 442-7472 October 5, 1993 Utility Board of Estes Park P. O. Box 1200 Estes Park, Colorado 80517 I Subject: 1993 Electric Rate Study i Gentlemen: 2 Submitted herewith is our letter Report setting forth our findings in reference to analysis prepared and results supporting electric rate modifications. The proposed rate modifications include rate changes for all current rate schedules. The specific rate modifications are discussed herein. The rate modifications also include increased off peak hours for the time of day schedules and a new Minimum Monthly Billing Demand clause for the Large Commercial schedules. Exhibit 4 attached to Section Il provides a cost comparison of the current and proposed rates. e New rate schedules are included for low consumption residential heat storage 1 customers, small commercial heat storage customers and for outdoor area lighting. The proposed rate schedules are attached as Appendix A. We wish to acknowledge the cooperation and assistance extended by the Light and Power Department (L&PD) management and staff in furnishing information and data which were basic to our analysis. Respectfully submitted, '211. F, Â·=ji~<6~f <:~,Â·k-6-0 621~w-zz< , r,IIZ, . 2 TABLE OF CONTENTS i t Electric Rate Study Light and Power Department Town of Estes Park, Colorado Section Page 1 Number Section Title Number Letter of Transmittal 2 Table of Contents 3 1 Executive Summary Introduction 4 Findings 4 1 Proposals 5 1 11 Integration of PRPA Rate Changes Introduction 7 Change in L&PD's Purchased Power Cost 7 Allocation to L&PD Rate Classes 8 Proposed Rates 9 Exhibit 1 - Allocation of PRPA Rate Changes 13 Exhibit 2 - Coincident Demand & Energy Allocations 14 Exhibit 3 - Estimated Monthly Energy & Demands 15 Exhibit 4 - Typical Bills Current & Proposed Rates 16 Ill Time of Day Rates Introduction 18 Time of Day Schedule Modifications 18 Time of Day Hours 18 Monthly Minimum Billing Demand 19 Off Peak Rate 20 Residential Service - Energy Time of Day 21 Commercial Service - Energy Time of Day 21 IV Outdoor Area Lighting Introduction 23 Outdoor Area Lighting 23 1. Appendix A 24 3 Section I Executive Summary 1 Introduction This study includes the analysis as outlined in the Agreement between the Town of Estes Park and M. E. Kiburz and Associates dated March 1993. The scope of services of the study includes: a) Incorporate the new (4/1/93) Platte River Power Authority (PRPA) wholesale purchased power rate changes into the L&PD rate schedules. To include adjusting the L&PD Purchased Power Rider to make the current PRPA rate the i schedule which became effective 4/1/93. 1 b) The change in the PRPA's method of determining the monthly billing I demands would be assessed as to the impact on the following rates and clauses in the L&PD rate schedules. i) The appropriateness of the current seasonal demand rates. ii) The appropriateness of the current demand ratchet clauses. iii) Evaluate the need to modify the rate schedules with time of day demand rates. c) Evaluate and propose new rate schedules for the following types of service. i) Residential time of day with only a customer and energy rates. i) Small Commercial time of day with only a customer and energy rates. iii) Security Lighting schedule which would include the cost of power and maintenance. : d) Prepare cost comparisons of proposed and current rates to show the dollar ! impact on varying energy use for the various customer.classes. Following this Executive Summary are Sections which discuss the findings and proposals of this study in greater detail. Section 11 includes a discussion of rate charge changes necessary to integrate the PRPA rate modifications. Section 11 also includes a j comparison of the current and proposed rates for various customer consumption's. The comparison is found on Exhibit 4. Section 111 includes the proposed changes for the Time of Day Hours and Monthly Minimum Billing Demand clauses. Section 111 also discusses the elimination of the off peak demand rates and the development of new 1 Energy Time of Day schedules. Section IV discusses the development of the proposed ' Outdoor Area Lighting rate schedule. Appendix A found at the end of this Report shows all the proposed rate schedules. 11 Findings 1. Rate modifications are necessary to account for the following changes in the I PRPA rate schedule. a) Increase in the demand charge. b) Increase in the energy charge. c) Change in the method of determining the billing demand. 2. The implementation of the proposed rate modification will have the following impact on the test year rate class revenues. 4 . 1 Purchased Power Allocated Proposed Rider Cost Study Rates Residential $40,194 $48,272 $48,369 Residential Demand 8,325 8,081 8,021 ; Residential TOD (2) 57 15 374 I Small Commercial 21,170 27,227 27,270 Large Commercial 27,145 14,551 14,545 Municipal 3,093 2,147 2,149 Total $99,984 $100,293 $100,728 Notes: 1) The above figures reflect revenue decreases. 2) The proposed rates includes the revenue decrease associated with the elimination of the off peak demand rate. 3. A comparison of typical bill for the rate class with varying consumption's is shown on Exhibit 4. Exhibit 4 is found at the end of Section 11. 4. The Residential Service, Residential Service Time of Day and Small Commercial schedules will receive a greater decrease than under the current Purchased Power Rider. 5. The remaining customer classes will receive less of a decrease than under the current Purchased Power Rider. 6. The difference in the allocated cost study test year revenues and the current Purchased Power Rider results because under changes in the PRPA rate the L&PD's purchased power cost for energy increases and for demand decreases. 7. The change in the PRPA billing demand method allows the L&PD to expand the time of day hours to include week ends and holidays. 8. The change in the PRPA billing demand method allows the L&PD to ' eliminate the time of day schedule off peak demand charge. 9. The offering of new Residential Service and Small Commercial Service - Energy Time of Day schedules is appropriate to encourage the use of heat storage units. 10. The offering of a new Outdoor Area Lighting schedule is appropriate and h offers a service generally available from electric utilities. 111 Proposals We are proposing the following as a result of the studies and analysis included herewith. 1. The proposed rate charge changes included in Appendix A should be adopted. 5 . i 2. The time of hours clause should be changed to the following. "The on-peak and off-peak periods applicable to service hereunder for billing purposes shall be as follows: On-peak period: The time between 6:00 and 22:00 on weekdays. Off-peak period: The time between 22:00 and the succeeding 6:00 on weekdays and all hours on weekends and holidays. Holidays excepted from the on-peak period presently are: New Year's Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day and Christmas Day. The on-peak and off-peak periods are subject to change from time to time." 3. The Large Commercial Monthly Minimum Billing Demand clause should be changed to the following. "The Light and Power Department reserves the right to assess a Monthly Minimum Billing Demand of 60% of the customers measured demand occurring during the months of Platte River Power Authority's seasonal . peak demand" 4. The proposed new Residential Service Energy Time of Day schedule for residential heating customers with annual consumption under 20,000 kWh should be adopted. 5. The proposed new Small Commercial Service Energy Time of Day schedule for commercial customers with heat storage devices should be adopted. 6. The proposed new Outdoor Area Lighting schedule for all customers who take electric service from the L&PD under another schedule should be adopted. 6 Section 11 Integration of PRPA Rate Change Costs 1 Introduction The Purchased Power Rider schedule allows the L&PD to pass on changes in the cost of power purchased from PRPA. The Purchased Power Rider is based on PRPA rates effective January 1, 1991. Since January l, 1991 PRPA has had rate changes which became effective April 1992 and April 1993 and which were passed on by the L&PD using the Purchased Power Rider. The Purchased Power Rider factors were based on a flat charge per kWh. The factors are shown below: April 1992 $.00234/kWh April 1993 ($.00118/kWh) The PRPA rate includes demand and energy rates. The old (1/91) and the new (4/93) PRPA electric rates are compared below. QW_(ltall New (4/93) Demand ($/KW) 10.40 10.78 Energy ($/kWh) .0132 .014 The billing demand method is also changed. The billing demand change is discussed in greater detail in Section Ill of this Report. Even though the demand and energy rates increased the change in the billing demand method results in an overall decrease in purchased power costs for the L&PD. The cost impact of the new PRPA rates is developed in this section. This section also classifies the PRPA rate change costs to demand and energy and allocates the cost impacts to the L&PD's rate classes. This section includes a discussion of the proposed rate designs and a cost comparison between the current and proposed L&PD rates. 11 Change in L&PD's Purchased Power Cost The impact of the new PRPA rates on the cost of the L&PD's purchased power cost is shown on the following table. PRPA Change in Power Cost Test Year - Twelve Months Ended March 31,1993 Basic Data: Billing Units Winter Summer Total Demand (KW-Months) 95,326 87,763 183,089 Coin. Dem. (KW-Mon) 94,483 66,216 160,699 Energy (kWh) 48,379,218 40,994,900 89,374,118 Dollars (OId PRPA rate (1/91) $10.40/KW and $.0132/kWh) Winter Summer Total Demand Dollars 991,390 912,735 1,904,125 Energy Dollar 638,606 541,133 1,179,739 Total 1,629,996 1,453,868 3,083,864 7 - . 1 Dollars (New PRPA rate (4/93) $10.78/KW and $.014/kWh) Winter Summer Total Demand Dollars 1,018,527 713,808 1,732,335 1 Energy Dollars 677,309 573,928 1,251,237 Total Do||ars 1,695,836 1,287,736 2,983,572 Dollars Difference Winter Summer Total Demand Dollars 27,137 (198,927) (171,790) Energy Dollars 38,703 32,795 71,498 i Total Dollars 65,840 (166,132) (100,292) The above are from PRPA invoices and additional coincident demand data f provided by the L&PD. Based on a test year ended March 31, 1993, the new PAPA rate is estimated to decrease the demand costs by $171,790 and increase the energy cost by $71,498 for an overall decrease of $100,292. The purchased power riders have passed on the PRPA rate changes based on a flat $/kWh surcharge on all kWh sold by the L&PD. However, as the above table shows the PRPA change in the demand and energy classified purchased power cost are impacted differently by the new PRPA rate. Therefore, modifications are necessary to the L&PD rates to take into consideration the difference between the use of the $/kWh Purchased Power Rider and the new PRPA rate design. The allocation of the purchased power demand and energy classified cost to the L&PD rate classes is discussed in the next section. Ill Allocation to L&PD Rate Classes Exhibit 1 summarizes the allocation of the total PRPA purchased power costs to the various L&PD rate classes. The total seasonal energy and demand dollars are from the table included in the previous subsections above. The seasonal demand and energy dollars are allocated to the rate classes using the allocators developed on Exhibits 2 and 3. Exhibit 1 shows dollar decreases for all L&PD rate classes. The rate class seasonal demand energy allocations of the purchased power cost change are used to set the level of the proposed L&PD rates. The implementation of the proposed rate modification will have the following 1 impact on the test year rate class revenues. Purchased ' Power Allocated Proposed Rider Cost Studv Rates Residential $40,194 $48,272 $48,369 Residential Demand 8,325 8,081 8,021 Residential TOD (2) 57 15 374 Small Commercial 21,170 27,227 27,270 Large Commercial 27,145 14,551 14,545 Municipal 3,093 2,147 2,149 Total $99,984 $100,293 $100,728 Notes: 8 1, 1) The above figures reflect revenue decreases. 2) The proposed rates includes the revenue decrease associated with the elimination of the off peak demand rate. Exhibit 2 shows the seasonal rate class coincident demand and energy allocation factors. The MWh of energy sales by rate class are from Exhibit 3. The Exhibit 3 sales are from billing data provided by the L&PD. Seasonal energy allocators are developed for each rate class. The seasonal energy percentages are used to i allocate the winter and summer total energy dollars to the L&PD rate classes. 1 The coincident demand allocators are based on estimates of KW months and coincident factors. The seasonal KW months by rate class are summarized on Exhibit E 3. Exhibit 3 also states the assumptions used to estimate the seasonal rate class KW months. The KW months of billing demands by rate class (non coincident demands) plus estimated coincident factors from the 1991 Estes Park Electric Rate Study are used to estimate the rate class coincident demands shown on Exhibit 2. IV Proposed Rates The dollar allocations to each of the L&PD rate classes shown on Exhibit 1 are integrated into the L&PD rate schedules based on the following assumptions and , procedures. Residential Schedules There are three residential schedules each is addressed separately below. The Residential Service includes a customer charge and a single energy charge for all kWh consumed. The cost allocation study (Exhibit 1) supports a decrease in annual revenues of $48,272. The proposed rate is developed using a revenue model which calculates the revenues using the test period (twelve months ended March 31, 1993) number of bills and kWh sales. The model calculates the revenues with the current and proposed rates. The revenue decrease was made with the energy rate. The proposed and existing rates are shown below. Current Rate Proposed Rate Difference Customer 3.00 3.00 - Energy Charge ($/kWh) .06501 .06359 (.00142) Since there is no demand charge or seasonal rates, the total decrease is effected through the energy charge. The current Purchased Power Rider is a negative $.00118/kWh. The classification to demand and energy and allocation to the residential class resulted in a greater reduction for this rate class. Exhibit 4 at the end of this section compares the residential class current rates with the Purchased Power ' Rider with the proposed rates, The comparison shows that the residential customers will receive a slight decrease under the proposed rates. The Residential Service - Demand Metered schedule includes a customer r. charge, seasonal demand charges and a single energy charge. The cost allocation study (Exhibit 1) supports an annual revenue changes as shown below. Demand Demand Winter Summer Enerqv Residential Demand $2,497 ($16,585) $6,008 The allocated unit cost adjustment for this rate class is ($.00145/kWIi) which is slightly less than the Purchased Power Rider factor of ($.00118/kWh). 9 i r The application of the above annual revenue changes to the various residential demandÂ·rates resulted in the following proposed rates. The current rates are also shdwn. 1 Current Rate Proposed Rate Difference ; Customer 3.00 3.00 - 1 Winter Demand ($/KW) 7.00 7.15 .15 ; Summer Demand ($/KW) 5.00 3.93 (1.07) Energy Charge ($/kWh) .03 .03085 .00085 Th-e winter demand rate and the energy rate increased. - Customers served ' under this schedule will have increased cost for the winter season. The summer season electric costs will be less than the current rate. A typical bill comparison for the i winter and summer seasons for the current rates with the ($.00118/kWh) factor and the proposed rates is found on Exhibit 4. The Residential Service - Time of Day schedule includes a customer charge, seasonal on peak demand char#es, off peak demand charge, on peak energy charge and an off peak energy charge. There is currently one customer served under this rate schedule. The following modifications are proposed to this rate. 1. Elimination of the off peak demand rate. i 2. Increase the off peak hours to include holidays and week ends. 3. Reduction of the off peak energy rate. The discussion on the need for modifications 1 and 2 is found in Section Ill of this Report. The reduction in the off peak energy rate is to account for the $15 allocated cost reduction shown on Exhibit 1 for this rate class. This rate schedule is not included on Exhibit 4. A comparison of the current and proposed rates is shown below. Current Rate Proposed Rate Difference 1 Customer Charge 3.00 3.00 - Winter On Peak Demand 8.00 8.00 - Summer On Peak Demand 6.00 6.00 - Off Peak Demand 3.50 0.00 (3.50) On Peak Energy Charge .03 .03085 .00085 Off Peak Energy Charge .0255 .025 (.0005) Small Commercial Service , The Small Commercial Service includes a customer charge and a single energy charge for all kWh consumed. The cost allocation study (Exhibit 1) supports a decrease in annual revenues of $27,227. The proposed rate is developed using a revenue model which calculates the revenues using the test period (twelve months ended March 31, 1993) number of bills and kWh sales. The model calculates the I revenues with the current and proposed rates. The revenue decrease was made with the energy rate. The proposed and current rates are shown below. Current Rate Proposed Rate Difference Customer 7.25 7.25 - Energy Charge ($/kWh) .07044 .06892 (.00152) Since there is no demand charge or seasonal rates, the total decrease is effected through the energy charge. The current Purchased Power Rider is a negative $.00118/kWh. The classification to demand and energy and allocation to the 10 1 â€¢ r commercial class resulted in a greater reduction to this rate class. Exhibit 4 at the end of this section compares the small commercial class current rates with the Purchased Power Rider with the proposed rates. The comparison shows that the small ' commercial customers will receive a slight decrease under the proposed rates. Large Commercial Schedules The Large Commercial Service schedule includes a demand charge and an energy charge. The cost allocation study (Exhibit 1) supports an annual demand ~ revenue decrease of $33,884 and an annual energy revenue increase of $19,333. The I proposed rate is compared to the current rate below. Current Rate Proposed Rate Difference Demand Charge ($/KW) 9.65 9.26 (.39) Energy Charge ($/kWh) .02875 .02959 .00084 The allocated unit cost adjustment for this rate class is ($.000633/kWh) which is slightly less than the Purchased Power rider factor of ($.00118/kWh). This difference is because the Large Commercial class load pattern results in a smaller allocation of the total negative demand dollars. In addition to the rate modifications, the Monthly Minimum Billing Demand clause is being changed. A discussion of this change is included in Section Ill of this Report. Exhibit 4 found at the end of this section shows a comparison of typical bills uhder the current rates with the Purchased Power Rider and the proposed rates. Exhibit 4 shows a billing comparison for customers whose billing demands are not impacted by the 60% ratchet. Exhibit 4 shows that customers whose billing demands are not reduced by the elimination of the 60% ratchet will be receiving a slight increase in their monthly power costs. Customers whose billing demand units are reduced because of the elimination of the 60% ratchet will have a reduction in their monthly power cost. During the test year approximately twenty customers had reduced billing demands. Also since the demand rate decreased and the energy rate increased Exhibit 4 shows that the higher load factor customers will receive slightly greater rate increases than low load factor customers. The Large Commercial Time of Day schedule currently is not used by any L&PD customers. The schedule modifications include: 1. Elimination of the off peak demand rate. 2. Increase in the on peak energy rate. 3. Increase in the Time of Day hours to include week ends and holidays. 4. Change in the methodology for determining the Monthly Minimum Billing Demand. The above modifications are discussed in detail in section Ill of this Report. This schedule is not included in the Exhibit 4 comparison of typical bills. Municipal Service The Municipal Service rate is a single energy rate which is proposed to change from $.06298/kWh to $.06216/kWh. The decrease is $.00082/kWh as compared to the Purchased Power rider of a negative $.00118/kWh. This difference is because of the municipal classes load pattern (higher monthly load factor) which results in less of an allocation of the reduced PRPA demand dollars. 11 The municipal rate is included on the Exhibit 4 comparison of typical bills. Purchased Power Rider The Purchased Power Rider schedule's effective date for the Current PAPA I , Cost term has been changed from January 1, 1991 to April 1,1993. This modification ' reflects the up date and the integration of the PRPA rate changes into the L&PD rate modifications proposed in this Report. 12 BAÂ©ic lit- ts 3 31 A 4- N W â€ž U) SE- 9- ,- M 01 00 091-1- M -1 CD 0 0 9. CHI 4. Lo C) NI r r r V}IN 0 0 te co 2 62 31 CO O 4- C) O LOI LO m >1 LON-COLDÂ¢90) Q Q e 1% OR. 0111 E ~ N e A M 41 N 5 2 20 â‚¬04> 0 U Lu 6 co g59 El - O- col cO- 4- ,-1 lo 01 r 01 0 1-1 0 0 CO N N 09 LOI (9 09 N 0 00 NO 0 co 4 -11% A of 4100 0 0 01 (9 CO U} L.0 4- 0 011 h - c\,1 4 41 09 0 0 lo col r- 10 7- â‚¬01,~ CO CO N U) U) U) E-E g S %3 55 2 (0(9=1- (9 4- 10 CD 00 00 00 00 06 06 06 06 N (9 4- 10 0 Â· ANANN 71 &81 Residential $14,414 S~%77 $31,191 ($91,521) ($79,463) ($77,108) $28,836 ($48,272) &82 Residential Demand $2,497 434 ($16,585) ($14,516) ($14,089) $6,0 8 08,081) (168'00 LS) (06Z' LZ LS) 1*$) E (ZE6'86 L$) Demand Energy Demand Demand Enerav Residential TOD $42 ($71) ($57) ($56) ervice Small S12,326 ($47,322) ($39,553) ($42,29 ) 88'EES) (089'82$) ED'88$) 86]81 80!Ala SE'DS) ( 66'*$) ied!0!un TOWf FORFP~~R~e~Cll~ges (1) Test Year - Twelve Months Ended March 31, 1993 EXHIBIT 1 Allocation o Winter 'E U.q!4)<3 wo# 812 SJOieoolle ABieue pue puewea (L) uodew s!41 JO Il uo!108SJo 8 pue Z saBed luoU (3) ESTRID.XLS :Saloulood 1 . I CD ColE 4- 32 g (0 0 0 52 0 32 2- A-% #-8 - cvE Xic)259 Q ' -4 16/Zigi 2 /5- 9 81 E :- im 8% r V- .-,- &3 32 32 h c) ip -2 00 \2 -2 E o co r. o- 62&6 CNg NI 0 - 1.Q : N N 00 ('i --- Lri tfi C\' cu (9 1 Lo r. W C) f 0 9 32 0 01-0*0 4-NE 32gbRy 1.0 (D C\1 1 O*<10 0 00 LO- 00_ 8 0 Wt h lf) 0 ged E-Ey 53 = 53- E6 2 i,- 5~ E Â©6 0 00 4 0 12 0 32 g 32 C\1 g g 09 col O in - h 2 Nog . 83 & 0 Â»1Â· to Co CH r. co g 00 4 4 C 06 06 :1 53 0, tri 22% M If) ' 9-1- 09 h =Ef g8Â£e CON %2 0 - th gRe5 0 -* m 0 00 0 0 00 2 W 00 2 g Woo cy g 0 32 (9 0 â‚¬ 32 !2 32 32 5 DRI R : 4 1 N O 84.- - -h O -com m 06 10 N d A oci (D Riti X U. LU - 10 2 3< 9 32 32 Egg *=*R Mhulâ‚¬ Â°Â°-al *~%568 0 32 0 Ce 1 o ob U) C <C 9 0 ~29 E-% Maq 0 0-3 0 1 13 2 Iii 9 8 % E .5 E 16 EE - M .= C t 8*%O8E .gm &*td8:Â§ M:* 5-0"12 E 0 22@lE< -C O 0 U. u 16 B a 9=%5~2@@ . M -r, 5 .9 E (0 6. M B g E .6 a E 52 .1 %*312.8 ..g 22 52__10_OLLIOOLLI 5 SJO_OLLIU)LLI 023EhE 0 w 4- a #WMV -C C m- 4A 4,104 87,746 Rate Class 71 &81 72&82 74&84 76&86 Total 00.00% 44.79% 55.00% Coincident Demand and Energy Allocator by Rate Class %0049 TOWN O ESTES PARK Twelve Months Ended March 31, 1993 easonal KW-Months 1~R~ 02 38 71 &81 'se/UnO JOwed peO7 SnS]eA 10108:I eoueppu!00 adil A.128 uo peseq .lopenuappu!00 C O and KW-Months -Month emand 1<W-Months % _ lojeoollv Winter Season :aloN ESTRID.XLS 1 imm 2%Â¢NA~.15. NOM CA-Ati M. 18%$ U~ m h C) Cl 28 V Z C NER m [A 2 101 f 3 h 00 M I MN c# 0> 09 - 0 ! P . a- af- 8-5.15- m 8 m 8 2 S m m 00.0*2 *.usM 4- cy - - 51 2 2 45%81Â§*ME r m CH - 00. d U- Di M tri V km Al g CD d M W 1% C) d g 8 9! . pl A- N h - *. m 152 K M N 00- ' g* 0;212222 2 PR 0, E E U) So 3 E & a= W. ~ h m M 8 e In 2 20; g in 4 v M ANggE (D 3 %% 9% z . cy uiti! 01 - - N W Â·A M â‚¬ 227% Or-N Ng/WE 31 M 2-Rk - 4,9, 4 N - C} .11 Co- -- -C,GIa)Â»hoo R WRRE 0 N O [9 h A -S.RE -CN - u, r- LS ~ 3.% 0 CO 0 CO .Â§ 0 Ul Cy t~ M = - Cy MOO R 28 .32 ul -- 2 W he C) Ln ,- W 01 Ul. f W %! m <8 Cy 9 4 W hm Egg ~C~Â¤~MEER 9 09 01 2 1:n =Wh =52 - U~ 00. -- 1 *lS Zgglm he In E NE ; m 450 - Cul I rt 0 - M Be Â· Ul cy ,} ~| 2/ 0-5.0 r. 822. 258= E (0 1.0 e 0, to 0 10 O 0 CD Ul - 0 - C\1 - I n Ul CH * m m g =S 4 K 20 >.C -0 1.- 8 2 g 8 EN 1 8 5 0 8 3 A 332 1 y. 001 }- 12,- 0 1.LIMWJ -C 2 3 1 -2 m -2 = JaCKIE :2 .% 3S 3 3 5 5%3335 6 2 C) 01 # 0 C EQ - 0 Al it Ic 14 ARRIRR @1 ES@EMES May June 22!x. Au~~. Sept. O Â· Â· Ja Feb. March Summer Winter Total emand 729,395 452,528 414,464 344 15 283,1 5 854,626 986,1 .503 4,4 6,642 7,055,145 19.338 232.121 214,487 171,195 ~89280 6,634,~f 244.746 1.341,824 2,620,796 Total General Service Small (4) ~295 32,736 70,22 rOLI 227 Uz?n N YAV Atvs 9691-19 %,0.El, %9624 961Â£9* PARK n &81 Resid 3,066,534 2,251,798 2,335,498 2.351,316 2,331,0 7 2,568,391 2, 77,816 ,346 3,535,823 4,042,8 14,904.584 19,158,212 34,062,796 Service Small 1,353,016 1,22 866,5 .034 1,478,560 1,639,117 1295,678 278 8. 338,458 17,94 , 5,715,610 6,410,163 6,798,345 7,085,596 7,257,790 8,196,352 6,538,521 44.195,539 84,731,287 12~41 '~,~353 bLE 11 09 1 ,98 1 2 1 81,561 105,657 187 Demand (3) 2631 2520 15.423 16,574 31 Service Large 769 1,881,086 1,889,154 1,882.845 10,829,315 23,00 73 &83 Resid ntial OD 5,603 ,243 2,0 6 3,637 6,403 6,739 16,856 1,088 1 093*ZSL 19*'92 LZ+'9Â£ 999'93 IDiOt ZEZ'LE S~'22 CZE 62*'t'Z ESTIMATED MONTHLY ENERGY AND DEMAND Test Year Ended March 31, 1993 (1) ts 9909 (s) 9618-1 agmas le,eueD 2 6'61 90+'El 981'El 629'Ek 823'81 pueutaa Vdk:Id PamseeM tuaullmdeo Jemod plle 146rl Mled S 3 q pep.oid elep Bu!11!q utoJ:I 93210 ewl S!41 10; 9!4 pugulap painspall, S, UPAol UJOJa Â·pedul! lat.ple, elÂ·11 Jo e/ysnpxa em pue Lltuow euo Aq e jep ao!OAU! 841 691 SpLIEU.lap Vdwd palnsee ~e~~ ! *14;uoill %5Â£ e 6u!11.insse pateums Â·Jope; ppol Alqluou-1 %St e 5u!UJnSSE pate'll!:S o Jop pe Al juoul e Builunsm paleut!;s3 41 Joi SpUELL,ap pate~no[20 uo pase , 1 Â§*23:00 I' â€¢884 râ€¢ â€¢ 812*32*E R ~ 3 Mg8 8 0,2 01 222%~! 8:8:8028 . 1 UNN?40. o Al M AW tri 812:1&1%4 @04*WK p --9. Rf ' 8 w CD 4- 39 LO cO Â§ 9 'BERS 1 ZNMAS'< N 2 g .. 9 - imaÂ©*ty 9 9 1 * . â€ž9 24@GMN /0 0 0 N .O N CD w 8 9 5 /9 W 8@*REWil @RgER#i N B @9 9 cd 0%~020 M % 0 3 8 0 w W W q 9 N Â§@WhiZE r R n' 9 6 ": 0 12*8@022 8%209F 10 O CO N. d H O 1- 1- (9 0 0 72;Whcui i 8 6- Gi h: 4 2~Aw r r d 1 N El 'r ' N r or) *24 9 K 1 8 N o g â„¢ w WEFRE.9 9 T =8 3: E M 8 6 D % M W cv 5 ~* N N jj~ ~ ~ cS ui 212%~4,< 8 58323 R 8 2 2 0 5 8 l.0 0 to LO g O h U) O 10 U) -0 0 'r r lf) 111 r 2-4 0 h r W Ul Â©C! &; hoc! u~ + ,.: r- 068:#N EuiUMUici _If) N rNW 4- 9 Ici - 1.0 0 . N r -4 r . 4- Ci; 1 U)8823222 U,88%32*Z 8851.Â°9"- - N â„¢ â„¢ o Â©ci 1~Wtii Eot<GN# 0061<~om ' r N (ID 04 0 aIN 4, 2=85 81= Lote Pi 51 33 6 81 LO te t; 2 83 8 E 8 9 3 32 8 2 t co Â©o cv 4 9 W~WBAN . j y M rjui -44&9* m 9 M Â· . 0 0 1 0 00 0 w &1 10 R! 0~, ~ p 0, LO IB :8 &1 2 2 2 Kin*8 cri o O 10 (1 10 7 T- O U)9009.N 1<NOO ir) LO Â· E 3 .E m C E 1 1 E E Â£ R Â£ CO Â£ R v 0, S g m s E lE aI E 0'm E E P~= 62 (2' m ( t.1, 4) (D 5 0' Â· 0 00 9 M 0 a O 0 -E ~) 8 21 02(0 0 02%Â° 2 e.00Â£-9 -92,0% 3 -vo.cr E 0 -5! $ m -n w 0 2 * EO c *m-*=ES- -92*=M-*=ma 38>*%2-23 2-- ~*GE-222 2 J 2 0, & Â£ lii x d Â£ 2 8 Â£ 0 - W -* O 0- a. 0 9 2 00. a. O 0- E .M On_ 0- 0 0 [C m K 0 6.51 TOWN OF ESTES PARK Typical.Bills.Current and Proposed Rates Minimum ESTCOMP.>C-S sidential 4MWs:uao paso ./. j I '. 0 -a Cl. L 3 .O tO A W 0. C) O N CO c\! g ui 8 0. e 0- r- h bo 0 0 . 0 Â¤ 8.amm ch Or 0- 4 E 0 In (11 O 2E Or -0 0 0 RO R@S! 0! W O 1--- Â¥- CO CO 8 R 98@1961 000 Ngh~Ui Ud 86 10 O M N R M M LO M O 0 If) 1-8*9*355,2 Â§*RERA N 23 WMV OW 3 2 0 0 0 re v- R 2 a. . ~8@RERZ 3 j f A g RI 0 8 hu-3 82kfit:Ui N Ed & d 2 RI 0 RE ".000 ~ if} " o- r. to 8 !9 0; 32 g gj M 0 0 a. 04 Bi i# N tri NuilriEOW /0 0 h r Â¤000 Â·Â¥- '-.- d a ./ C) 0 8 0 81 0 8 81 0 0 M 9 m "Ud[300 r (,0 (D 0 O to 0, 1 I O' m E @Pd 02 0~62v . E EU 71 3!EO #i & m E E 0. a) 8-K! & 0 3 R w v - Ec %%%2@-0- *E M W O M al) <00-0-00- a.xoo-0-00. ialm~R i 17 Current Prcposed Current Current Propo ed Current Proposed 9 LE90-0 96290-0 69620-0 szÂ£60Â·0 tr>0200 69Â£90'0 10990-0 9 L L00-0- 0 L LOO-O- 9 L 100'0- 9 L 100'0- 9 L LOOD 200 27375 73000 4,3UM 3 posed $ 626.51 1,666.53 4,444.08 Residential Residential Deman Small Comm. Large Comm 619.52 3,55484.~~ 37.2 39.9; 2.28% 0.58% TOWN OF ESTES PARK Typical Bills Current and Proposed Rates ESTCOMP.nS Large Commercial oposed Cents/kWh urrent J BUJUins 01 Section 111 Time of Day Schedules 1 Introduction Modifications are proposed to the Time of Day Hours and Monthly Minimum Billing Demand clauses and the off peak demand charge. The modifications which are discussed later in this section reflect changes made by PRPA in the wholesale rate under which the L&PD purchases power..This section also includes a proposed Residential Service and Small Commercial - Energy Time of Day schedules. The Energy Time of Day rate schedules are intended to encourage low use residential and commercial heating customers to use heat storage devices during the winter season. 11 Time of Day Schedule Modifications The current PRPA wholesale schedule includes revisions in the method of determining the L&PD's billing demand. The L&PD's PRPA billing demand is currently determined based on the seasonal L&PD demand occurring at the time of the PRPA system peak. The season-al L&PD demand is set at the seasonal maximum demand occurring during the previous six months of the same season until another maximum demand is established. In the utility industry this is known as 100% seasonal ratchet. The PRPA seasons are defined as winter (October 1 - March 31) and summer (April 1 - September 30). The PRPA seasons are the same as used by the L&PD. The PRPA change in the method of determining the L&PD's billing demand provides the support for the proposed changes to the time of day L&PD schedules discussed below. Time of Day Hours It is proposed that the number of hours defined as off peak be expanded to include week ends and holidays. The proposed time of day hours clause is stated below. "The on-peak and off-peak periods applicable to service hereunder for billing purposes shall be as follows: On-peak period: The time between 6:00 and 22:00 on weekdays. Off-peak period: The time between 22:00 and the succeeding 6:00 on weekdays and all hours on weekends and holidays. Holidays excepted from the on-peak period presently are: New Year's Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day and Christmas Day. The on-peak and off-peak periods are subject to change from time to time." The table below shows how the change in the PAPA's method of determining the L&PD's billing demand has changed the day of the L&PD's billing demand. The table is developed using billing demands for the twelve months ended December 31, 1992. 18 f . I'' f Billing Demands Old PRPA Rate New PRPA Rate Billing Billing Month 1221 Time KW Dav --.- Time EW Jan 92 Wed 8:00 15,870 Wed 18:00 14,625 Feb. Wed 8:00 15,005 Mon 19:00 12,969 Mar. Sat 20:00 14,469. Wed 19:00 11,857 i Apr. Wed 8:00 14,347 Thr 15:00 10,918 M ay Mon 11:00 14,760 Tues 15:00 10,918 June Tues 22:00 14,461 Tues 14: 00 10,918 July Fri 19:00 14,714 Mon 15: 00 11,154 Aug. Wed 21:00 14,849 Fri 17:00 11,154 Sept. Sat 21:00 14,632 Mon 16:00 11,154 Oct. Thr 9:00 14,430 Wed 18:00 14,636 Nov. Wed 18:00 15,590 Tues 18:00 15,359 Dec. S at 18:00 16,376 Wed 18:00 15,736 The day and time for the old PRPA rate are for the L&PD peak demand, not the billing demand. The table demonstrates that when the L&PD's billing demand is determined coincident with the PRPA seasonal peak demand, the L&PD's billing demand occurred during a week day. Under the old PRPA billing demand method the L&PD's billing demand was set on a Saturday three times during calendar year 1992. The old PRPA billing demand method was based on the L&PD's system load pattern, which recognized that the L&PD's service area is a holiday/vacation designation. Thereby, frequently causing the billing demand to occur on a week end or holiday. The old PRPA billing demand resulted in the L&PD's time of day schedule excluding week ends and holidays. The new PRPA billing demand method is based on the PRPA system peak demand which includes the other PRPA members demands. Under the new PRPA billing demand method the other members influence the time of the PRPA seasonal peak demand. The other PRPA members do not peak on week ends and thus the PRPA billing demand for the L&PD does not occur on the week ends. This difference allows the expansion of the off peak hours to include week ends and holidays. The proposed change in the Time of Day Hours clause is included in the proposed time of day schedules included in Appendix A. Monthlv Minimum Billing Demand The new PRPA method of determining the L&PD's billing demand also requires a change in the Monthly Minimum Billing Demand clause. The clause is proposed to be changed to the following. "The LigMt and Power Department reserves the right to assess a Monthly Minimum Billing Demand of 60% of the customers measured demand occurring during the months of Platte River Power Authority's seasonal peak demand" 19 i . I I , f The proposed clause eliminates the determination of the billing demand based on 60% of the customers peak demand occurring during the previous months of November through March. The proposed clause has no minimum billing demand ! provision unless the L&PD determines that the customers load pattern is creating a PRPA purchased power demand penalty. The following table shows the impact on the I billing demand units for the proposed clause. The following statistics are for the i customers currently served under the Large Commercial schedule. ; Billing Units (KW-Months) f Twelve Months Ended March 31, 1993 Increment Billing Units Above Measured Summer Winter Summer Winter Measured Demand 29,509 28,848 - - Old Clause 30,369 29,304 860 456 t The above table shows that the new clause would change the billing demand I units by approximately (860 KW-months) for the summer season and 456 KW-months for the winter season. The approximate 2.2% decrease in the billing demand units increases the demand rate by $.20/KW. The clause change results in customers without a minimum monthly billing demand having a slight rate increase and customers with a minimum monthly billing demand having a slight rate decrease. The clause change is partially supported by the PRPA change from a winter i peak billing demand calculation to a 100% ratchet of the seasonal peak demand at the time of the PRPA peak. The new Monthly Minimum Billing Demand clause is included in the Large Commercial schedules shown in Appendix A Off Peak Demand Rate The current Residential and Large Commercial Time of Day schedules include an off peak demand rate for all KW's that the off peak demand is in excess of the on peak demand. The review of the consumption pattern of the one customer on the Residential Time of Day schedule shows that the off peak demand rate is increasing the customer's average cost for the summer months. The summer is a season when the L&PD would not incur additional cost to provide the off peak demand. The customer's winter season usage did not show a significant difference between the on and off peak demands. Therefore, the current schedule off peak demand rate had no s impact on the winter season cost, however, the off peak demand substantially increased the summer season cost. To remedy this inequity the proposed time of day schedules off peak demand rate is eliminated. The Appendix A proposed schedules include the above recommendation. There is very little operating experience for the time of day schedules, therefore it is recommended that as operating experience becomes available the time of day schedules should be reviewed and if necessary modified. The L&PD currently has one customer on the time of day residential rate and none on the Large Commercial time of day schedule. The elimination of the off peak demand rate is estimated to reduce the L&PD's revenues by approximately $376. 20 I, 1 111 Residential Service - Energy Time of Day Schedule Pursuant to the scope of services a new residential time of day schedule was developed. The new schedule is included in Appendix A. The schedule is designed for r.esidential customer's with heating storage devices and annual consumption less than 20,000 kWh . Heating customer's with consumption greater than 15,000 kWh have two current schedules from which to take service. The schedule has a winter season on and off peak energy rate. The summer I season rate is the same as the Residential schedule. Since the rate does not offer a time of day rate for the summer season, the winter season is increased to include October 1 through May 31 to provide electric service for the total heating season. The i other clauses included in the Residential Service - Energy Time of Day schedule are the same as other current applicable residential schedules. This schedule is offered to encourage low consumption residential heating customers to use heating equipment which would shift electric consumption to the off peak hours. The following table shows the winter season average rate for varying percentages of on and off peak consumption. The average rate at the 70% on peak and 30% off peak consumption pattern fesuits in an average rate which is approximately the same as the non time of day residential schedule. The time of day winter schedule allows the customer to achieve a lower average cost by increasing their off peak consumption. Residential Time of day Schedule Average Rate versus On/Off Peak Consumption Percent on Peak use 50 60 70 80 Percent off Peak use 50 40 30 20 Average Rate $/kWh .0535 .0580 .0635 .0690 The proposed Energy Time of Day schedule will require monitoring and may change as more experience is gathered on residential customer's use pattern. Additionally, as more experience is gained with this new rate, the L&PD may want to increase the winter off peak hours to include 10 am to 1 pm on week days. These extra off peak hours would allow a recharge of the heat storage devices. IV Small Commercial Service - Energy Time of Day Schedule Pursuant to the scope of services a new small commercial time of day schedule was developed. The new schedule is included in Appendix A. The schedule is designed for small commercial customer's with heating storage devices and who would otherwise be served under the small commercial schedule. The schedule has a winter season on and off peak energy rate. The summer season rate is the same as the Small Commercial schedule. Since the rate does not offer a time of day rata for the summer season, the winter season is increased to include October 1 through May 31 to provide electric service for the total heating season. The other clauses included in the Small Commercial Service - Energy Time of Day schedule are the same as the other current clauses applicable to the small commercial schedule. This schedule is offered to encourage low consumption small commercial heating customers to use heating equipment which would shift electric consumption to the off peak hours. The following table shows the winter season average rate for varying percentages of on and off peak consumption. The average rate at the 70% on 21 . A peak and 30% off peak consumption pattern results in an average rate which is approximately the same as the non time of day small commercial schedule. The time f of day winter schedule allows the customer to achieve a lower average cost by i increasing their off peak consumption. Small Commercial Time of day Schedule Average Rate versus On/Off Peak Consumption 1 Percent on Peak use 50 60 70 80 Percent off Peak use 50 40 30 20 Average Rate $/kWh .0559 .0620 .0682 .0744 The proposed Energy Time of Day schedule will require monitoring and may change as more experience is gathered on commercial customer's use pattern. Additionally, as more experience is gained with this new rate, the L&PD may want to increase the winter off peak hours to include 10 am to 1 pm on week days. These extra off peak hours would allow a recharge of the heat storage devices. 22 . 0 Section IV Outdoor Area Lighting 1 Introduction The scope of services included the development of an outdoor area lighting schedule. The proposed outdoor area lighting schedule is included in the attached Appendix A. The following section discusses the conditions of service and cost, equipment and operating assumptions. i 11 Outdoor Area Lighting The outdoor area lighting schedule is proposed to be available to all customers who are taking service under another L&PD electric rate schedule. The customer requesting service under the outdoor area lighting schedule will be responsible for the installation, at the customer's expense, of all lighting equipment and extensions necessary to connect the customer's lighting equipment to an existing L&PD secondary distribution line. The monthly rate of $5.25 is based on the following costs, equipment and operating assumptions. Customer installs necessary equipment at the customers cost. Lamp size of 150 watts high pressure sodium kWh based on 55% annual load factor 964 kWh Cost of providing electric power $.045/kWh Annual electric power cost $43.38 Lamp replacement and general maintenance $20.00 Annual Cost $63.38 Monthly Cost $5.28 The outdoor area lighting schedule includes six conditions of service. The conditions are briefly summarized by number below. The conditions of service can be found in there entirety on the Outdoor Area Lighting schedule included in Appendix A. 1. Minimum one year term. 2. L&PD will provide maintenance and power. 3. Customer will provide installation. 4. Lamps to burn from dusk to dawn. 5. Customer will notify L&PD of service failure and L&PD will schedule repair during normal business hours. 6. All lighting equipment installed will become the properly of the L&PD. 23 APPENDIXA i Proposed Rate Schedules Rates Paae . 1. Residential Service 25 2. Residential Service - Energy Time of Day 26 3. Residential Service - Demand Metered 27 4. Residential Service - Time of Day 28 5. Small Commercial 29 6. Small Commercial - Energy Time of Day 30 7, Large Commercial 31 8. Large Commercial - Time of Day 32 9. Municipal Service . 34 10. Outdoor Area Lighting 35 11. Purchased Power Rider 36 ELECTRIC RATES RESIDENTIAL SERVICE APPLICABILITY Applicable in Estes Park service territory. AVAILABILITY This Schedule is available to residential consumers for all domestic uses in individually metered single- family private dwellings or individually metered apartments except new electric space heating consumers. Effective January 1,1994, existing consumers in this schedule having electric heat as a priinary or auxiliary energy source for space heating with annual consumption's greater than 20,000 kWh will be transferred to the Residential Demand rate. This rate is not available for resale service. MONTHLY RATE Customer Charge' $3.00 Energy Charge per kWh $.06359 MONTHLY MINIMUM BILL The Monthly Minimum Bill shall be the Customer Charge. PAYMENT The above rates are net. Bills for electric service are due and payable within ten CIO) days subsequent to mailing or delivery of the bill. CONDITIONS OF SERVICE Service provided under this rate schedule shall be subject to all Light and Power Department general and specific Rules and Regulations and extension policies and such rules and regulations as set forth in appropriate tariff sheets on file. PURCHASED POWER RIDER This schedule is subject to the conditions set forth on the Purchased Power Rider. J. ?04 1 9 4 43\ A ..JO V 25 rami ELECTRIC RATES RESIDENTIAL SERVICE - ENERGY TIME OF DAY APPLICABILITY Applicable in Estes Park service terfitory. AVAILABILITY This schedule is available to all residential consumers who use energy storage equipment for heating and have an annual energy consumption under 20,000 kWh. This schedule in not available for resale service. MONTHLY RATE Customer Charge $3.00 Energy Charge: Winter Season (10/1 - W31): On-Peak Period: All kWh used On-Peak in the Billing Period, per kWh $.08 Off-Peak Period: All kWh used Off-Peak in the Billing Period, per kWh $.025 Summer Season (6/1 - 9/30): All kWh used per kWh $.06359 TIME OF DAY HOURS The on-peak and off-peak periods applicable to service hereunder for billing purposes shall be as follows: On-peak period: The time between 6:00 and 22:00 on weekdays. Off-peak period: The time between 22:00 and the succeeding 6:00 on weekdays and all hours on weekends and holidays. Holidays excepted from the on-peak period presently are: New Year's Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day and Christmas Day. The on-peak and off-peak periods are subject to change from time to time. MONTHLY MINIMUM BILL The Monthly Minimum Bill shall be the Customer Charge. PAYMENT The above rates are net. Bills for electric service are due and payable within ten (10) days subsequent to mailing or delivery of the bill. CONDITIONS OF SERVICE Service provided under this rate schedule shall be subject to all Light and Power Department general and specific Rules and Regulations and extension policies and such rules and regulations as set forth in appropriate tariff sheets on file. Any account requesting service under this schedule shall be required to remain on this schedule for not less than twelve (12) months. PURCHASED POWER RIDER U Pkj This schedule is subject to the conditions set forth on the Purchased Power Rider. lr< j >ep / V 9- 4% 0 44 '9 1 26 ELECTRIC RATES RESIDENTIAL SERVICE - DEMAND METERED APPLICABILITY Applicable in Estes Park service territory. AVAILABILITY This schedule is available to residential consumers having electric heat as a primary or auxiliary energy source for space heating in individually metered single- family private dwellings or individually metered apartments. This schedule is also available for those residential consumers who do not have electric heat as a primary or auxiliary energy source for space heating, but whose annual energy consumption is over 15,000 kWh. This schedule is not available for resale service. MONTHLY RATES Customer Charge $3.00 Demand Charge per KW of billing demand. Winter Season Oct.1 - Mar. 31 $7.15 Summer Season Apr. 1 - Sept. 30 $3.93 Energy Charge per kWh $.03085 DETERMINATION OF BILLING DEMAND The billing demand shall be determined by suitable meter measurement of the highest 15-minute integrated demand occurring during the monthly billing period. MONTHLY MINIMUM BILL The Monthly Minimum Bill shall be the Customer Charge. PAYMENT The above rates are net. Bills for electric service are due and payable within ten (10) days subsequent to mailing or delivery of the bill. CONDITIONS OF SERVICE Service provided under this rate schedule shall be subject to all Light and Power Department general and specific Rules and Regulations and extension policies and such rules and regulations as set forth in appropriate tariff sheets on file. Any account provided service under this schedule shall be required to remain on this schedule for not less than twelve (12) months. PURCHASED POWER RIDER This schedule is subject to the conditions set forth on the Purchased Power Rider. GY b 9 27 ELECTRIC RATES RESIDENTIAL SERVICE - TIME OF DAY APPLICABILITY Applicable in Estes Park service territory. AVAILABILITY i This schedule is available to all residential consumers whose annual energy consumption is over 15,000 kWh. This schedule in not available for resale service. MONTHLY RATE Customer Charge $3.00 Demand Charge: On-Peak Period: All KW of Maximum Demand in the Billing Period Per KW Winter Season (10/1-3/31) $8.00 Summer Season (4/1-W30) $6.00 Energy Charge: On-Peak Period: All kWh used On-Peak in the Billing Period, per kWh $.03085 Off-Peak Period: All kWh used Off-Peak in the Billing Period, per kWh $.025 TIME OF DAY HOURS The on-peak and off-peak periods applicable to service hereunder for billing purposes shall be as follows: On-peak period: The time between 6:00 and 22:00 on weekdays. Off-peak period: The time between 22:00 and the succeeding 6:00 on weekdays and all hours on weekends and holidays. Holidays excepted from the on-peak period presently are: New Year's Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day and Christmas Day. The on-peak and off-peak periods are subject to change from time to time. MONTHLY MINIMUM BILL The Monthly Minimum Bill shall be the Customer Charge. DETERMINATION OF DEMAND The billing demand shall be determined by suitable meter measurement of the highest 15-minute integrated demand occurring during the monthly on peak period. PAYMENT The above rates are net. Bills for electric service are due and payable within ten (10) days subsequent to mailing or delivery of the bill. CONDITIONS OF SERVICE Service provided under this rate schedule shall be subject to all Light and Power Department general and specific Rules and Regulations and extension policies and such rules and regulations as set forth in appropriate tariff sheets on file. Any account requesting service under this schedule shall be required to remain on this schedule for not M less than twelve (12) months. PURCHASED POWER RIDER This schedule is subject to the conditions set forth on the Purchased Power Rider. 20 L ELECTRIC RATES SMALL COMMERCIAL SERVICE APPLICABILITY Applicable in Estes Park sen/i~e territory. AVAILABILITY This schedule is available for business lighting and small power loads of 35 KW maximum demands or less. All service will be supplied only through a single meter. This service is available at single or three phase at established voltages available of either the Town's primary or secondary distribution system. Effective January 1, 1993, residential consumers in this schedule utilizing electric space heating with annual consumption exceeding 20,000 kWh will be transferred to the Residential Service - Demand Metered rate. Effective January 1, 1993, residential consumers in this schedule utilizing electric space heating with ' annual consumption less than 20,000 kWh will be transferred to the Residential Service rate. This 1 Schedule is not available to new residential consumers. This schedule is not available for resale service. MONTHLY RATE Customer Charge $7.25 Energy Charge per kWh $.06892 MONTHLY MINIMUM BILL The Monthly Minimuni Bill shall be the Customer Charge. PAYMENT The above rates are net. Bills for electric service are due and payable within ten (10) days subsequent to mailing or delivery of the bill. The foregoing schedule shall be net where service is metered at secondary voltage of the Town's distribution system. Where service is metered under this schedule at primary voltage, the consumer shall receive a credit of two percent (2%) of the monthly bill less the Customer Charge. CONDITIONS OF SERVICE Service provided under this rate schedule shall be subject to all Light and Power Department general and specific Rules and Regulations and extension policies and such rules and regulations as set forth in appropriate tariff sheets on file. PURCHASED POWER RIDER This schedule is subject to the conditions set forth on the Purchased Power Rider. 29 ELECTRIC RATES SMALL COMMERCIAL SERVICE - ENERGY TIME OF DAY APPLICABILITY Applicable in Estes Park service territory. AVAILABILITY This schedule is available to all small commercial consumers who use energy storage equipment for heating and otherwise would be served under the Small Commercial schedule. This schedule in not available for resale service. MONTHLY RATE Customer Charge Â· $7.25 Energy Charge: Winter Season (10/1 - 5/31): On-Peak Period: All kWh used On-Peak in the Billing Period, per kWh $.0867 Off-Peak Period: All kWh used Off-Peak in the Billing Period, per kWh $.025 Summer Season (6/1 - W30): All kWh used per kWh $.06892 TIME OF DAY HOURS The on-peak and off-peak periods applicable to service hereunder for billing purposes shall be as follows: On-peak period: The time between 6:00 and 22:00 on weekdays. Off-peak period: The time between 22:00 and the succeeding 6:00 on weekdays and all hours on weekends and holidays. Holidays excepted from the on-peak period presently are: New Year's Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day and Christmas Day. The on-peak and off-peak periods are subject to change from time to time. MONTHLY MINIMUM BILL The Monthly Minimum Bill shall be the Customer Charge. PAYMENT The above rates are net. Bills for electric service are due and payable within ten (10) days subsequent to mailing or delivery of the bill. The foregoing schedule shall be net where service is metered at secondary voltage of the Town's distribution system. Where service is metered under this schedule at primary voltage, the consumer shall receive a credit of two percent (2%) of the monthly bill less the Customer Charge. CONDITIONS OF SERVICE Service provided under this rate schedule shall be subject to all Light and Power Department general and specific Rules and Regulations and extension policies and such rules and regulations as set forth in appropriate tariff sheets on file. Any account requesting service under this schedule shall be required to remain on this schedule for not less than twelve (12) months. 4 /\r .d>L PURCHASED POWER RIDER This schedule is subject to the conditions set forth on the Purchased Power Rider. \ 9 42Y1 ~94 I r a f f 44 4 4< 1 TV 30 1 . 1 ELECTRIC RATES LARGE COMMERCIAL SERVICE APP. LICABILITY Applicable in Estes Park service territory. AVAILABILITY This schedule is required for electric lighting and power requirements of consumers having maximum demands exceeding 35 KW in any two (2) consecutive months. All service will be supplied only through a single meter. This service is available at single or three phase at the established voltage of either the Town's primary or secondary distribution system. This schedule is not available for resale service. MONTHLY RATE i Demand Charge per KW $9.26 Energy Charge per kWh $.02959 DETERMINATION OF BILLING DEMAND The billing demand shall be determined by suitable meter measurement of the highest 15-minute integrated demand occurring during the monthly billing period, but shall not be less than the Monthly Minimum Billing Demand. MONTHLY MINIMUM BILLING DEMAND ~ The L&PD reserves the right to assess a Monthly Minimum Billing Demand of 60% of the customers measured demand occurring during the months of Platte River Power Authority's seasonal peak demand. MONTHLY MINIMUM BILL $9.26 times the Monthly Minimum Billing Demand or $55.00, whichever is greater, plus the monthly energy charge. PAYMENT The above rates are net. Bills for electric service are due and payable within ten (10) days subsequent to mailing or delivery of the bill. CONDITIONS OF SERVICE Service provided under this rate schedule shall be subject to all Light and Power Department general and specific Rules and Regulations and extension policies and such rules and regulations as set forth in appropriate tariff sheets on file. The consumers shall be required to properly balance their loads. If the power factor during the time the billing demand is established falls below 95% lagging, adjustment may be made by increasing the measured demand for each month by 1 % for each 1 % or major fraction thereof by which the power factor during the billing period is less than 95% lagging. The foregoing schedule shall be net where service is metered at the secondary voltage of the Town's distribution system. Where service is metered under this sche8ule at primary voltage, the consumer shall receive a credit of two percent (2%) of the monthly bill for service. Where service is taken at the Town's established primary voltage and the consumer furnishes the transformers and substations converting to secondary voltage, the consumer shall receive a credit of four percent (4%) of the monthly bill. Any account requesting service under this schedule shall be required to remain on this schedule for not less than twelve (12) months. PURCHASED POWER RIDER This schedule is subject to the conditions set forth on the Purchased Power Rider. 3.-lf te V 1?Jn 31 . . ELECTRIC RATES LARGE COMMERCIAL SERVICE - TIME OF DAY APPLICABILITY Applicable in Estes Park service territory. AVAILABILITY This schedule is required for electric lighting and power requirements of consumers having maximum demands exceeding 35 KW in any two consecutive months. All service will be supplied only through a single meter. This service is available at single or three phase at the established voltage of either the ' Town's primary or secondary distribution system. This schedule is not available for resale service. MONTHLY RATE Demand Charge: On-Peak Period: All KW of Maximum Demand (including Power Factor Cost Adjustment) in the Billing Period Per KW $10.70 Energy Charge: On-Peak Period: All 1<Wh used On-Peak in the Billing Period, per kWh $.02959 Off-Peak Period: All kWh used Off-Peak in the Billing Period, per kWh $.02444 TIME OF DAY HOURS The on-peak and off-peak periods applicable to service hereunder for billing purposes shall be as follows: On-peak period: The time between 6:00 and 22:00 on weekdays. Off-peak period: The time between 22:00 andthe succeeding 6:00 on weekdays and all hours on weekends and holidays. Holidays excepted from the on-peak period presently are: New Year's Day, Memorial Day, Independence Day, Labor Day, Thanksgiving Day and Christmas Day. The on-peak and off-peak periods are subject to change from time to time. DETERMINATION OF BILLING DEMAND The billing demand shall be determined by suitable meter measurement of the highest 15-minute integrated demand occurring during the monthly on peak period. The on peak billing demand shall not be less than the Monthly Minimum Billing Demand. MONTHLY MINIMUM ON PEAK BILLING DEMAND The L&PD reserves the right to assess a Monthly Minimum Billing Demand of 60% of the customers measured demand occurring during the months of Platte River Power Authority's seasonal peak demand. MONTHLYMINIMUM BILL $10.70 times the Monthly Minimum On Peak Billing Demand or $55.00, whichever is greater, plus the monthly energy charge. PAYMENT The above rates are net. Bills for electric service are due and payable within ten (10) days subsequent to mailing or delivery of the bill. f 32 l CONDITIONS OF SERVICE Service provided under this rate schedule shall be subject to all Light and Power Department general and specific Rules and Regulations and extension policies and such rules and regulations as set forth in appropriate tariff sheets on file. The consumer shall be required to properly balance their loads. If the power factor during the time the billing demand is established falls below 95% lagging, adjustment may be made by increasing the measured demand for each month by 1 % for each 1 % or major fraction thereof by which the power factor during the billing period is less than 95% lagging. The foregoing schedule shall be net where service is metered at the secondary voltage of the Town's distribution system. Where service is metered under this schedule at primary voltage, the consumer shall receive a credit of two percent (2%) of the monthly bill for service. Where service is taken at the Town's established primary voltage and the consumer furnishes the transformers and substations converting to secondary voltage, the consumer shall receive a credit of four percent (4%) of the monthly bill. Any account requesting service under this schedule shall be required to remain on this schedule for not less than twelve (12) months. PURCHASED POWER RIDER This schedule is subject to the conditions set forth on the Purchased Power Rider. 33 ELECTRIC RATES ! MUNICIPAL SERVICE APPLICABILITY Applicable in Estes Park service territory. AVAILABILITY ' Available for municipal street, park lighting and buildings as provided to the Town. MONTHLY RATE 6 All kWh used per kWh $.06216 ; PURCHASED POWER RIDER This schedule is subject to the conditions set forth on the Purchased Power Rider. 34 ELECTRIC RATES OUTDOOR AREA LIGHTING APPLICABILITY Applicable in Estes Park service territory. AVAILABILITY This schedule is available to any customer for the lighting of private outdoor areas, where such service can be provided directly from existing secondary distribution lines of the Estes Park Light and Power Department. MONTHLY RATE 150 watt high pressure sodium lamps, burning dusk to dawn per month $5.25 PAYMENT The above rate is net. Bills for electric service are due and payable within ten (10) days subsequent to mailing or delivery of the bill. PURCHASED POWER RIDER This schedule is subject to the conditions set forth on the Purchased Power Rider. CONDITIONS OF SERVICE Service provided under this rate schedule shall be subject to all Light and Power Department general and specific Rules and Regulations and extension polices and such rules and regulations as set forth in appropriate schedule sheets on file and the following special conditions. 1. All service under this schedule shall be for a minimum of one year and thereafter until termination, where service is no longer required on five days notice. 2. The Light and Power Department under this schedule will provide maintenance of the outdoor area lighting equipment and furnish the necessary electric energy. 3. The customer shall at its expense furnish and install all outdoor area lighting equipment necessary to connect the installation to the Light and Power Department existing secondary distribution system. The customer's proposed outdoor area lighting equipment and plan shall be subject to the approval of the Light and Power Department prior to the construction of the installation. The Light and Power Department shall have the right to make modifications to the equipment and plan in accordance with good engineering practice. 4. The term "burning dusk to dawn" as used herein shall be construed to mean that all lamps shall be lighted by automatic control equipment from approximately sunset to sunrise. 5. Customer shall notify the Light and Power Department of any service failure. Burned out lamps shall be replaced as soon as practicable, subject to Light and Power Department operating schedules, after notification by customer of service failure. All maintenance, including replacement of lamps, will be done during regular working hours. No credit shall be allowed on customer's monthly bill for lamp outages. 6. All materials and equipment furnished and installed by either the customer or Light and Power Department shall be the property of the Light and Power Department, and the Light and Power Department shall have a reasonable time after the termination of service to disconnect the Light and Power Department area lighting facilities. If customer terminates service before the expiration of the initial contract period, the Light and Power Department may require customer to reimburse the Light and Power Department for the total expenditure made by the Light and Power Department plus cost of removal of the facilities installed less the salvage value ther~f. ~j y g ' RJ- m .U id. 4 9 j 9 1 . I , ELECTRIC RATES Â· PURCHASED POWER RIDER APPLICABILITY Applicable in Estes Park service territory to all Electric Rate schedules. PURPOSE ' This schedule is to pass-on the estimated cost change resulting from changes in the Platte River Power Authority base electric rates which are applicable to service to the Town of Estes Park. METHOD OF DETERMINING THE RIDER ' Formula for determining the Purchased Power Rider: Purchased Power Rider = (New PRPA Rate Cost - Current PRPA Cost) kWh Sales Current PRPA Cost = The most recent twelve months cost of power purchased from PRPA by the Town of Estes Park estimated using the rates in effect April 1,1993. kWh Sales = The electric kWh sales to the Town's customers for the same twelve month period as the Current PRPA Cost. New PRPA Cost = The calculated cost of power assuming the power purchased for the same twelve month period as used for the Current PRPA Costs and the proposed PRPA rates. The purchased power rider shall be calculated to the nearest one-hundredth of a mill ($0.00001) per kWh. The electric rate schedules with demand rates may have the purchased power rider spread between the energy and the demand rates. The demand portion shall be set as $/KW. 36 TOWN OF ESTES PARK October 6, 1993 OFFICE MEMORANDUM TO: Light and Power Committee FROM: Richard E. Matzke-/2.7,Â«rÂ·- SUBJECT: Prospect Mountain Proposed Lease Agreement Attached is a proposed lease agreement between the Town, the National Park Service, and Robert and Nell Frances Heron allowing the.Town to construct and maintain its radio facilities on Prospect Mountain. The previous agreement, which expired at the end of 1992, had a five year term, covered an unspecified number of transmitters, and cost the Town $1000 per year. The' proposed agreement lists the Towns existing facilities and calls for additional rent if the Town installs facilities in addition to those listed. The rent for the first year of the agreement is $2,400 with annual increases indexed to the Denver CPI. The proposed agreement has a five year term with option to renew two additional five year terms. This agreement will provide the Town with a long term location to operate its radio equipment. The cost of the lease will be prorated among the departments which use the radio equipment involved. The Light and Power Department recommends that the mayor be authorized to execute this agreement for the Town. REM 3-1 LEASE AGREEMENT THIS LEASE AGREEMENT is entered into this day of , 1993, between ROBERT HERON and NELL F. HERON (Lessors) and THE TOWN OF ESTES PARK, COLORADO (Lessee). The parties agree as follows: 1. LEASE OF PREMISES. The Lessors do hereby lease to the Lessee the right to operate radio transmission and reception systems located in buildings and towers owned by the Town of Estes Park, the National Park Service, and the U.S. Bureau of Reclamation all located on land owned by the Lessors; and to use the access road across the Lessors' property for ingress and egress purposes, all located on the Prospect Mountain radio site near Estes Park, Larimer County, State of Colorado, and all subject to the following terms and conditions: 2. USE The Lessee shall be entitled to non-exclusive use of the operation of transmission and reception of radio communication systems listed in Exhibit "A" and access to the radio site. The site shall only be used for the installation, operation and maintenance of communication equipment. 3. TERM The term of this lease shall be for five (5) one (1) year periods commencing on the first day of January 1994 and ending on the 31st day of December 1998. The Town shall have the right to terminate this lease agreement by giving Lessor sixty (60) days notice in writing prior to the end of any calendar year. In said event, this lease shall terminate on December 31st of that year. The Lessee shall have the option to extend this lease for two (2) additional five (5) one (1) year periods. The Lessee shall give the Lessor written notice of its intent to extend this lease at least six (6) months prior to the base term, or any extended term, such notice to be in writing and delivered to Lessors at the address specified in Paragraph 8 hereof. In the event that this lease is extended for the additional period, all terms and conditions of this lease shall remain in force and effect. 4. RENT Upon the commencement date, and annually thereafter, the Lessee shall pay the Lessors, as rent, the sum of Two Thousand Four Hundred Dollars ($2,400.00) annually (rent). Rent shall be payable on the first day of each 12-month period, in advance, to the Lessors at the Lessors' address recited in Paragraph 8 hereof. The rent shall increase for radio systems installed in addition to those listed in Exhibit "A." Lease Agreement 1993 11, ron/Vown of Es{,3 Park 6 pages 1 , Unless otherwise mutually agreed, the annual rental increase shall be the percentage increase in the Consumer Price Index for the Denver (City) Metropolitan Statistical Area. The Lessors shall be responsible for communicating the amount of the rental adjustment to the Lessee and shall provide supporting data, if any, upon which the adjustment is calculated. The percentage increase shall be payable on the next annual payment. If this Lease is terminated at any time as the result of Lessee's default, no rentals shall be prorated as of the date of termination. The parties agree and acknowledge that this Lease Agreement does not constitute a multiple-fiscal year debt or financial obligation of the Lessee based upon the Lessee's ability to terminate this Lease Agreement pursuant to Paragraph 3 of the Lease. Lessor acknowledges that Lessee has made no promise to continue to budget and appropriate funds beyond each fiscal year and that Lessee's only obligation is to pledge adequate financial reserves for the fiscal year of 1994 and all subsequent calendar years in which Lessee has exercised its option to renew. Lesser understands and agrees that in the event that I.essee terminates this Agreement, pursuant to the provisions of Paragraph 3, that the obligation of Lessee for any further payments to Lessor is terminated. 5. LIABILITY The Lessee shall provide the Lessors with certificates of liability insurance for general liability insurance in an amount of no less than One Hundred Fifty Thousand Dollars ($150,000) per person, and Six Hundred Thousand Dollars ($600,000) per occurrence, and Fifty Thousand Dollars ($50,000) property damage, naming the Lessors as additional insured on the policy or policies. Lessee may satisfy this requirement by obtaining appropriate endorsement to any umbrella policy or liability insurance the Lessee may maintain. Lessee may provide for property insurance set forth above partially or wholly by means of a self insurance fund as provided by law. The parties understand and agree that the Lessee is relying on, and does not waive or intend to waive, by any provision of this Lease, the monetary limitations (presently $150,000 per person and $600,000 per occurrence) or any rights, immunities and protections provided by the Colorado Governmental Immunity Act, Section 24-10-101, et seq. C.R.S., as from time to time amended or otherwise available to Lessee or any of its officers, agents or employees. The Lessors will not be responsible for any losses of any kind, including but not limited to, fire, theft, vandalism, hazardous road or weather conditions, fluctuations of power voltage, wind, or lightning. 6. INDEMNITY Lessee agrees to indemnify, protect and save harmless the Lessors from any and all claims, demands and liability for any loss, damage or injury, including death, or other like or different casualty to persons and property used by and growing out of, or happening in connection with Lessee's use and occupancy of the aforesaid premises, and any equipment located or to be located thereon, due to the negligence of Lessee, its agents, servants, or employees. Lease Agreement I 993 Heronfl'own of Ested Park 6 pages 2 7. CONDITION OF SITE During the Initial Term and any Renewal Term, the Lessee shall be responsible for any and all damages to the site caused by or directly attributed to any actions by the Lessee or its representatives. Upon termination or expiration of this Lease Agreement, the Lessee will surrender its use at the site in good condition except for damages due to causes beyond the Lessee's control or without its fault or negligence. The Lessee further agrees not to construct any additional improvements upon the site without the prior written approval of the Lessors. 8. NOTICES All notices required or permitted hereunder shall be in writing and shall be deemed given if personally delivered or mailed, certified or registered mail, return receipt requested, or sent by overnight carrier to the following addresses: If to Lessors, to: Robert Heron and Nell F. Heron 2135 South Monroe Street Denver, CO 80201 If to Lessee, to : Town Administrator Town of Estes Park P.O. Box 1200 Estes Park, CO 80517 Or if a more current address, or name, has been given to the other party in writing, to such other address, or name. 9. WAIVER Failure or delay on the part of the Lessors to exercise any right, power or privilege hereunder shall not operate as a waiver thereof. 10. DEFAULT If any rent shall be more than ten (10) days past due or the Lessee shall be in default of any of its other obligations hereunder and such default shall continue for a period of more than thirty (30) days after written notice thereof, then the Lessor may terminate this Lease Agreement and declare the rent for the entire remaining term of this Lease Agreement immediately due and payable and proceed to collect the same, or the rent for the entire remaining term of this Lease Agreement immediately due and payment of rent provided that such acceptance shall not constitute a waiver of the requirement for timely payment of rent as provided herein. The Lease Agreement 1993 Heron/Town of Estes Park 6 pages 3 . . Lessee agrees to pay, in addition to all sums hereunder, all of the Lessor's costs in enforcing its rights under this Lease Agreement, together with the Lesser's reasonable attorneys' fees, if any. 11. ASSIGNMENT The Lessee shall not assign its rights under this Lease Agreement or any interest herein, or convey the whole or any portion of the leased area, without the prior written consent of the Lessors. 12. ENTIRE AGREEMENT This Lease Agreement constitutes the entire agreement of the parties hereto with respect to the subject matter hereof and supersedes all prior offers, negotiations, and agreement, whether written or oral, between the parties hereto with respect to the subject matter hereof. 13. TAXES Lessee shall pay any personal property taxes assessed on, or any portion of such taxes attributable to, the facilities belonging to the Lessee. Lessors shall pay when due real property taxes and other fees and assessments attributable to the property in an amount not to exceed the amount of the 1992 taxes. Lessee shall pay as additional rent any increase in real property taxes levied against the property or towers in excess o f the amount of taxes for the year 1992, payable in 1993, if it is determined that such increase is attributable to Lessee's use of the defined premises. 14. INTERFERENCE In the event that the Lessee causes any harmful interference to existing lessees; the Lessee must terminate or cure its operation within forty-eight (48) hours. The Lessee may then either remedy or remove its equipment. All responsibility and expenses related to interference shall be born by the Lessee and not the Lessors. If such interference cannot be eliminated, the Lessees may terminate this Lease by giving thirty (30) days notice prior to such termination. The Lessors will use their best efforts to prevent future lessees from causing harmful interference to the Lessee. All transmitters installed by the Lessees at the site shall be properly licensed and operated in accordance with the Federal Communications Commission (FCC) rules and regulations, and a copy of the license shall be posted with the transmitting equipment. All licensing and any subsequent licenses shall be at the sole expense and responsibility of the Lessee, including any penalty or enforcement imposed by the FCC. Lease Agreement 1993 Heronfrown of Estes Park 6 pages 4 15. CANCELLATION OF LEASE This Lease Agreement may be cancelled by mutual consent of the Lessce and the Lessors for non-payment of rent or any violations of the terms of this Lease Agreement. This Lease Agreement shall be irrevocable during its term and shall continue in force unless or until terminated by any of the parties hereto only in accordance with and as allowed under the terms of this Agreement. Thereupon, this Lease Agreement shall absolutely end. 16. IMPROVEMENTS Lessee shall have the right, at its expense, to place and maintain at the site improvements, personal property, and facilities, which include radio transmitting and receiving antennas and electronic equipment, and in addition, attached strubtures, all with the approval of the Lessors during the term of this Lease, with notice to the Lessors. The property placed upon the premises by the Lessee shall remain the exclusive property of the Lessee, and the Lessee shall have the right to remove its said property at any time in whole or in part and within any reasonable time following any termination of this Lease, if the Lessee shall not be in default at that time. 17. UTILITIES The Lessee will be responsible for the supply and payment of all AC and/or DC power used on premises by the lessee. 18. ACCESS Lessee agrees to keep the gate across the access road locked at all times. The Lessors are obliged to provide the Lessee with a key to said gate and will subsequently provide new keys as necessary when the lock to said gate is changed. It is agreed that the Lessors will not provide maintenance on the road during the winter months and that, therefore, the site may not be accessible. Inclement weather restricting access shall not impose a liability on the Lessors. Lease Agreement 1993 Heron/rown of Estes Park 6 pages 5 EXHIBIT "A" TOWN OF ESTES PARK RADIO SYSTEMS ON PROSPECT MOUNTAIN SYSTEM FCC LICENSE FREQUENCY BUILDING LOCATION Municipal 8805225761 159.315 Town Police CH 1 9107256134 159.910 U. S. Bureau of Reclamation CH 2 9107256134 155.475 Nat'l Park Service Fire Channel 8905235083 159.405 Nat'l Park Service Water Department 757759 952.35625 Nat'l Park Service Lease Agreement 1993 Heron/Town of Estes Part 6 pages 6 , 01 . 1 11 1 1 11 1 1 010 LA O I ID I 000000000101 01Ull Ull to .r 43 toi .-1(Na'.r-Ir-ILDIMI 1- tNI LAI I 0 1 01-0. 1 e | ,-14' r-1 r-1 CO q I r-1 1 (NINI Mt MIl 4 4 4 1 -1 .. . ..1 -1 -1 -1 -1 m E-I t q MOO 1 10 1 001.Dmoot-00 I eli ..IMI .11 m I t MLOO la, 1 '0 00'OLDO 101 m 1 w 1 0 1 1-1 >4 1 1- r-1 tool Mt-Mr-1 1.,1 1 N I <DIMI Int 1 1 .1 . 1 .1 1 1 /1 I m Imt .4 IMI 1 IM I 1 14 1 1 1 1 11 1 1 It 1 1 11 1 1 1 1 .4.4 lo 0 1 Co l moc,mmnlt-l 0101 toi 1 M r- ch 1 A 1 CO NION.-1 1.-1 1 CO 1 <1 1 lot At ioot- lot N .-14â€¢13Â£01(NI COINI '71 N 1 1 . - 1 .1 . -. ..1 .1 .1 -1 . 1 m E-1 I r-1 Ln M INI MOONA IOI ,-1 1 1-1 1 1-1 1 Chi 100 tall .1 r-1 94 I LA 1 4â€¢Im: 001 rIE ' V 19.1 1 .-1 I mi 1 r-1 1 1 Y 111 1 1 It '11 1 N CO LA /1' 1 Ch I ootommr-140 toi 0 1 9 1 7 1 1 .-1 cO mr- toi Net-Ir-ICAr-INI CO I tf) 1 1- 1 lul/Dul.rtâ„¢ 1 Mt-Â·Na.oor--lool m 1 00 1 W 1 Al . . ..1 .1 .... ..1 .1 .1 -1 -1 Mi I ~ooom 1 5 1 Mn.-10(nhÂ·I r-11 Ul l M 1 1-I t RE-1 1 NmOM tail m owgpi tool r-1 101 1 00 1 0,110 r-1 lot m OlAN 71 1 /71 toi 1 Ul l el >4 1 - 1 41 - 1 .1 1 1 -1 1 M 1.1 (N , IMI 1 I mi 1 Uk 11 1 INWAO 1Â©01 000(NMLON I .-1 1 1- 1 1- 1 00 1 0 11 1 1 1 It 1 1 1 11 U] M D 1 1.0 .7 0 10.1 (Nq'P-~rÂ·I lot ch 1 Q I w I m 11 WME-14 Â¢3 1 Ulc~Ul 1 0/ 1 . moo'â€¢mt.Diall O 1 LA 1 9' 1 in 11 E-4 3 0< 1 Mil . - - 1 .1 -- . .1 .1 .1 .1 . 1 . 11 [00 E-10 mEA I wicv Iml H NOMAINI 1-11 ,-11 9 1 Mil WAU]Z 0 1 I tri q 101 m LON N imt t-- 1 r-I t v t lA 11 H r-IE I V 1,11 N Imt 01 0 mI r-1 11 ElitÂ·ZI mCI , U} 1 1 1. 11 O ZZ I E-low 1 It It â€ž :: 1 1 1 11 0%0 3 0 Z U) OHH~C E-1 4 E-1 Z O ' 1 It 11 11 1 1 2 1 UloOO I lAi OONWOOI.-It 4â€¢INI MI 1 co O O 1 col 1-ON'-010 ILDI NINI 001 M Utmoo IMI NOU19'GNO IN 1 .-11Â£01 m Q) I . - - 1 -1 ... . ..1 .1 .1 -1 m ) 1 V O O 1 9.1 000,-ILO~e' 191 OINI 1 1 Ar[11 Lrl!~0 1.-11 lot.nommr-1101 r-11001 M r-1 21 1 0. 1-1 INI 1,1~00 mLO 1 col .1 1 " 1 1 1 O mi . 1 .1 . 1 ..1 1 1 -1 Ell I tri Il.DI m , in lilli 1 V, =f . (1) 4 0 1 It 1 1 1 11 1 1 11 11 11 1 It 1 1 1 1 1 It 1 1 1 1 11 /1 11 1 It 1 1 / 1 1 1 1 1 1 It 11 11 1 1 1 11 11 It , 1 U >1 3 - '-4 \ 1 C U u] C 01 0 ZW Â¤ C â€¢rt B~ 0 0 4.1 H 4-1 M U 0 014-1 4-3 W 1-1 1-1 WCOSII-14-1+J Â£4 A 0 +J ,-1 0 04 -rl .a a) U] U] (1) C â€¢4 01 0 -P I -1 E -1 (1) 0 Out) 01 4 E-1 <6 0 1-, o c 1-1 W 1-1 1-1 0 CD H k w V P Â·â€¢4 (1) b ro )-, 0 .p A 0) :1 10 0 E-1-1 k 4 1 â€¢A C Z 04 0 Â·rl Â¤'d C MUOTH MOU]CIOKH 8 4a ISO'ZEE$ IE9'OIE$ SES'SIS$ (86k'ZLE) S32[LLIGN3dX3 MEAO 31, 1993 & 1992 8 ' 98Z 9 S3EfLL IGNEd)3 ra,ZO,L 'IYLLIEVO 32IO.136 MILL NadX) MEAO for Services Transfers Out Current Capital Expenditures vernmental TOTAL REVENUE aneous Accounts SanNEASE JO ( ADNEIDI.ila) SSZOX3 Sa) SSEJX3 b * n M>1 1/\131SAS 4a-1 030 AON 130 d3S Dnv 1nr Nnr AVIAI BdV HVIAI 83=1 NVr TOWN OF ESTES PARK PURCHASE POWER - DEMAND 17,000 - 1991 1992 -E] 1993 19,000 - 18,000 - 16,000 - 15,000 - 000'* L - 000'EL - 000'EL il ! 000'LL 9391KW.XLC 10/6/93 . T -- 130 lilli 1111111111111111@Ill 111'1111111 Â®11 %11 l i li 1111 '2 daS 9nv 1 -- Â®Â¥111111~~*]Â®11!J~% M[=[1111UJJJ]]111]1111~JUW]J]wl!1WlilJ~#~WliUUÂ« My#imilk.*Al#' MVIN Â®m==111'112~EEE233% . 44., ,>V.ae.....:8/.Â«<... >:.5#.0.>:1.:<Qb:P.:1: 833 w]111[1~~~PWm~m~mmwmmmswmmmmHmiwmmmwmmwwmmmmmN 1 NVf HMM INBISAS 4a-2 9391 KWH.XLC 10/5/93 0 1991 7,500,000 - 2 1992 866 L E TOWN OF ESTES PARK PURCHASE POWER - ENERGY 9,500,000 - 9,000,000 - 8,500,000 - n 8,000.000 - 1 - 000'000'L 6,500,000 - -: - 000'000'9 - 000'009'9 , -- 330 AON i 100 ~~E~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~~ d36 I > 1- 1 co Z MO E~*19*1**iifilfaRR*#:11@10~ Â· &1 2 1 Onv ul > C: D:ft.~422,Â·~1,&4:#wea-*reiftgrahÂ·inri,.u:Â·464*Â£,*12 w i lAP B 2 u.1 A NAP 03 I ~.3 0 11 AVIN DC D -- Wdy BVIN ippiffiTE'/2 Â£13=1 NVf 1 HMM I/\81SAS 4a-3 9391 KWHA.XLC 10/5/93 C 1991 166 L // 866 L ~ TOWN OF ESTES PARK ACCUMULATED YTD B 95,500,000 - 85,500,000 - 75,500,000 - 65,500,000 - 55,500,000 - - 000'009'44 - 000'009'SE - 000'009'SE - 000'009'SL 000'009'9 I f ,. 0 CO 00 ' . 1 N I . m 330 AON 130 1 d3S inr >\"Fr>imwp.". Fium\"\Â»\\\\9%Â»*r ~0~0:144....107.:49..2.. - c ..0<kit -Â·.\~st.:Â·Â·>4<I'Â»~~ Â·2 U\Â»Â«~a\<a~Â«tualuk*al*t~1*~* Nnf k'*AFFbA-m'77*vtÂ»Â»eaÂ»rj.pmwi,~M~2.3..~~9%%~I~-,773 1424*4~11~Lka~11<2411,Kil 4 AVIN \ HdV -- HVIAI 83=1 . Nvr - 9nv ($) 1SOj JaMOd Alqjuov\I 4a-4 93PPSAV.XLC 10/6/93 Actual Bill E Previous Rate SDNIAVS ci31Â¥-In INAJOV - 000'OLZ L aBed 1993 Wholesale Power Cost Comparison 310,000 -- 290,000 - 270,000 - 250,000 - 230,000 - - 000'06 L - 000'OL L 000'09 L 1 1 h I -- &2&585&581U.5:211314=.EU :. Â®#'Ct,rÂ·â€¢,-0, -v.* , . p.~, 2- r ..... -..,7,2 ~ -: fl'- -C: :1.Lj B,ZIC@ AA=iÂ·.Aill %.Sti :=Ne 4, 1:42 ,-6 -c.wo,0,- Icili~.i...>,z.~C.hA.*212&:bL.;C-Â·Ul ' ".'.'... lili ... I" .. 0 0 0 CS LO ($) Salvs 4a-5 / 1991 //1992 866 L U 030 AON 100 deS Bnv Inr unr Ael/\1 Jdv lei/\I qe=1 uer ELECTRIC SALES BY MONTH 600,000 - 550,000 - - 500,000 - - '- 000'098 A 000'00* 9091SAL.XLC 10/5/93 *. -)â€¢'.."' % 'Â· ~. I 2 i.Â· ti~:t Â· Wt'.t.f !!'Â·ij :hm,%.i.Â·.14 t.t p I . '. H.**AP## -- *: ~ 'nj ,;i./?,4% 1 > Â·' i:.:1 < 3 )-, ~.1 '...i "â‚¬ Â·/ i~Â·fâ€¢ -1..Â·.:iÂ·iÂ·,:; '; Â· 21?,('#'li>44 14 -.â€ž-1, Al ..r.1 : 2 :19,:,Asti.42#jif, .... Â· 'f DHWN,1" 'i;'Â£11< 'AL:?â€¢l?f-k'14'Â·1: ~29 0Â·4*,(i,Â·,:1~:4441't?'Mt'9,91:.09i1.?ft; i Â·, i A, UCâ€¢. e,>.'Â·,li"E~'t~ , r, fNA?et,Â¢$143::.1 96 /41;~;04('1'4:Â·j)#W ' 9 2+6'AÂ·Â».c-Â· Â·Â· 19 -'e ':tr- ' ., 1 - 1,18:Â·11'ir..'<''i'..~47, '.4.'.'..~ .' ' 0 31Â¥0 01 HÂ¥3* ($) S31VS 4a-6 10/5/93 ACCUMULATED BY MONTH oaa AON 100 das 6nv Inf unr AelAI Jdv Je IN qed ue ELECTRIC SALES ~ 1991 YTD U 1992 YTD O 1993 YTD 6,000,000 - 5,000,000 - 4,000,000 - 3,000,000 - - 000'000' L 9091SALY.XLC - 000'000'Z TOWN OF ESTES PARK October 7, 1993 OFFICE MEMORANDUM TO: Light and Power Committee FROM: Richard E. Matzke722'~h SUBJECT: Current Transformer Metering Test Program Billing Adjustments Electric Customers with Multipliers The Light and Power Meter Department recently began a program of testing metering installations containing current transformers. These installations are used where the size of the customer's electric service exceeds the capacity of a self contained meter. A current transformer accurately passes a fraction of the customer's total load through the electric meter. For this reason, a multiplier is applied to the meter readings at these locations to determine the actual consumption for billing purposes. The Light and Power Department presently serves approximately 7,200 customers. Only 103 of these customers have multipliers, the vast majority being commercial customers. After testing five current transformer installations, meter department personnel discovered errors in the billing multiplier for two of those accounts. One customer was being billed for twice the actual consumption and the other was being billed for half the actual consumption. This rate of error was a cause of great concern and department personnel immediately undertook to verify the multipliers on the remaining 98 accounts with current transformer metering. That program has been completed and one other incorrect multiplier was discovered. Two customers were being overbilled and one customer was being underbilled. The customers that were overbilled have received a refund. The Department recommends that we not back bill the customer that was underbilled. All multipliers have been corrected and future bills for these accounts will reflect the actual consumption. The purpose of the testing program was to verify the accuracy of the meter installations. All five of the installations tested were within, acceptable limits. The program will continue until all installations have been tested. REM 4b-1