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<br />The estimated energy purchase expenses are b~sed on <br />kWh in FY 1982, 21 mills in FY 1983, 22 mills in FY <br />FY 1985 through FY 1989. <br /> <br />prices of 20 mills per <br />1984, and 23 mills for <br />, <br /> <br /> <br />3. Wheelin and Other Ex enSes. In lieu of building certain <br />transmission faci ities, arrangements inanclally advantageous to the CRSP <br />were made to utilize transmission systems of;various utilities. In Utah, <br />CRSP power is wheeled over the facilities ofiUtah Power and Light Company. <br />CRSP power was also wheeled by the CP National Corporation's system in Utah <br />until September 1981, when Utah Power and Li$ht Company purchased the <br />Corporation's Utah facilities. In New MexicO, power is wheeled over the <br />facilities of Public Service Company of New Mexico. In .Wyoming, power is <br />wheeled over facilities of the Bridger Valley Electric Association. Table 8 <br />shows the estimated future annual quantities, rates, and costs for <br />wheeling. The column marked "miscellaneous"; includes wheeling by Bridger <br />Valley and others. It has been assumed that! the existing rates will . <br />continue without change throughout the 1982-~090 period, and that the <br />amounts wheeled will vary with total availab~e CRSP capacity and energy. <br />The future annual costs are estimated to rea~h a maximum of $3,518,000 in <br />FY 1990 and a minimum of $2,722,000 in FY 2065 and thereafter. . <br /> <br />Column 6 of Table 2 is a tabulation of wheeling and other expenses. <br />In historical years, Column 6 includes wheeling expenses, interchange <br />expenses, and the value of CRSP-generated Hoover deficiency deliveries. In <br />future years, Column 6 includes only the estimated wheeling expenses and the <br />I . <br />OM&R and amortization cost of salinity cont~ol. Salinity control costs are <br />the Upper Basin's share of the cost of cons~ructing and operating salinity <br />control facilities above Imperial Dam (about 4%), estimated to start in <br />FY 1986. The average annual costs included [in the study are about $350,000. <br /> <br />O. Replacement Costs. Replacement costs have been capitalized since <br />FY 1973, as shown in columns 15 through 17 of the power repayment. studies. <br />Estimated replacement costs for FY 1982 through 1986 are based on the most <br />current program budget documents. Estimateq rep 1 acement costs thereafter <br />are based on projections that assume service lives of facilities established <br />in August 1981 and on original investment cQsts indexed to January 1981 cost <br />levels. [ <br />I <br />, <br /> <br />The interest rates applied to replacements ~re the same as those applied to <br />the repayment of capital investments, shown! on page 42. The total allocated <br />electric plant investment used in estimating replacement costs includes all <br />. electric facility costs plus an allocated portion of the multipurpose plant <br />investment. Service lives are based on theiAugust 1981 publication issued <br />by the Bureau of Reclamation and Western Ar~a Power. Admirristration titled <br />'Replacements: Units, Service Lives, FactorF' <br /> <br />E. Reimbursable Capital Investment Costs to be Repaid from Power <br />Revenues. <br /> <br />1. Cost Allocations. Table 9 ,shows the preliminary cost <br />allocations of the capital investment costs and interest during construction <br />as of the end of FY 1981 for the storage units, the Transmission Division <br /> <br />39 <br />