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However, the only costs affecting the power rates are those in the period through the rate setting points, i.e., through 2057 in the FY 1981 studies and through 2046 in the FY 1977 studies. Figure 3 is a pie-chart showing the amounts by which the FY 1978-2057 average annual costs in the FY 1981 studies exceed the FY 1978-2046 average annual costs in the studies using FY 1977 data. The average annual costs increased from $48 million to $73 ' million for a total average annual increase of $25.0 million. The largest share of the increase, $13.2 million or 52.6 percent of the total, is for O&M costs, $4.0 million or 16.0 percent for repayment of power investment costs, $2.7 million or 10.9 percent for aid to participating projects, $2.5 million or 10.2 percent for interest costs, $2.1 million or 8.4 percent for replacement costs, and $0.5 million or 1.9 percent for other items (primarily energy purchase costs). Figure 4 ts a pie chart showing the sources of power revenues to meet the average annual increases in costs between those in the present study and those used in the study for the existing rate. The largest average annual increase in revenues, $18.3 million or 73.0 percent of the total, is from firm power and peaking capacity sales, $3.6 million or 14.3 percent from fuel conservation revenues, $2.4 million or 9.7 percent from transmission service revenues, and $0.7 million or 3.0 pe~cent from other revenues, (Hoover Deficiency reimbursements, rental of facilities, and miscellaneous). The revised power repayment study indicates that a composite firm power rate of 10.06 mills per kWh at a 58.2 percent seasonal load factor, is needed to meet repayment requirements. This represents a 2.17-mill increase over the present rate. The study assumes that the proposed ,new rate will be effective April 1, 1983. For the proposed firm power rates, an equal share of costs at 58.2 percent seasonal load facto~ have been assigned to the capacity and energy components of the rate. 'This same allocation of costs was also used to establish both the original and existing rates and distributes the cost burden equitably among firm power customers. The proposed new rate schedules are as follows: Rate Schedule SP-F2 (Firm Power) Demand: $2.15 per kW-month Energy: 5.0 mills per kWh Rate Schedule SP-FP-2 (Peaking Power) Demand: $12.90 per kW-season ' The demand charge would continue to be based on the greater of the monthly maximum demand or the seasonal contract rate of delivery, and the rate for contract violations would continue to be 10 times the firm power rates. Figure 5 shows the composite firm power rates in mills per kWh at 58.2 percent seasonal load factor for historical and proposed rates. 13