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<br />and energy as the current firm power rates. This maintains the same <br />relative historical cost of capacity and energy. <br /> <br />The proposed firm power rate is: <br /> <br />Month 1y Rate <br /> <br />DEMAND CHARGE: $2.82 per kilowatt of billing demand. <br /> <br />ENERGY CHARGE: 6.64 mills per ki1owatthour of use. <br /> <br />BILLING DEMAND: The billing demand will be the greater of <br />(1) the highest 30-minute integrated demand <br />measured during the month up to, but not in <br />excess of, the delivery obligation under the <br />power sales contract, or (2) the contract <br />rate of delivery. <br /> <br />The complete proposed firm power rate schedule is shown in Appendix C. <br />Appendix D shows the effect of the proposed firm power rate on <br />individual Integrated Projects firm power customers. <br /> <br />Annual expenses and the investment costs of power and irrigation <br />features have been increasing since the existing power rate was <br />established. The FY 1981 CRSP PRS, on which the present rates are <br />based, covered the period of FYs 1964 through 2090, when repayment of <br />the last CRSP participating project is due. The FY 1989 Integrated <br />Projects Preliminary PRS covers FYs 1964 through 2080 because some CRSP <br />participating projects scheduled for repayment after 2080 do not meet <br />the criteria to be scheduled for repayment within the rate-setting <br />years, as discussed in Section VI.D.5. <br /> <br />Within every PRS, there is a year when annual expenses and investment <br />costs come closest to or exceed the available revenue. This year is <br />referred to as the "rate-setting year." Revenues must cover the costs <br />in the rate-setting year for a project to earn sufficient income. <br /> <br />Approximately 96 percent of the costs and revenues of the Integrated <br />Projects are attributable to CRSP. Adding RGP and Collbran does not <br />change the CRSP rate-setting year. The CRSP rate-setting year is <br />determined by revenue requirements for its participating projects. The <br />rate-setting year, FY 2057, in the FY 1981 CRSP PRS and the FY 1989 <br />Integrated Projects Preliminary PRS was determined by revenue <br />requirements for the Central Utah Project (CUP) in Utah. <br /> <br />The FYs 1982 through 2057 actual and projected average annual costs <br />used in the FY 1989 Integrated Projects Preliminary PRS exceed the <br />projected average annual costs for the same period in the FY 1981 CRSP, <br />Co1lbran, and RGP PRSs by approximately $25.9 million. The projected <br />average annual costs for the Integrated Projects increased as shown in <br />Appendix E. <br /> <br />The sources of average annual revenues to meet the projected average <br />annual costs also are shown in Appendix E. The firm power rate must be <br /> <br />6 <br />