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The capabilities are the maximum amounts that can be generated at each plant with all units operating. It is estimated that the Blue Mesa and Flaming Gorge Powerplants will be uprated by FY 1985 and the Glen Canyon Powerp 1 ant by FY 1987. Hydroe 1 ectri c generating capacity of the Central Utah participating project is estimated to include 133.5 MW on the Diamond Fork Powerplants startin9 in FY 1990 and 10.4 MW on the Jordanelle Powerplant starting in FY 1991. Addition of the aforementioned plants will brin9 the total capability to 1,912.9 MW. Power generated at the CRSP and participating projects is dedicated first to project pumping requirements and other project uses of the CRSP and the participating projects. The remaining project power is sold commercially to preference customers in the established market area. The market area includes all or parts of the states of Arizona, California, Colorado, Nevada, New Mexico, Utah, & Wyoming. Transmission facilities include a high-voltage transmission grid to deliver power to certain delivery pOints in the market area, to provide interconnections among the plants of the CRSP units and participating projects, and to interconnect with other existing Federal and utility systems wi,thin the market area. Additional transmission facilities are planned in order to improve system reliability, to provide for the accommodation of inadvertent power flows from other systems, to conserve fuel by better coordination of thermal and hydro resources, and to allow delivery of power from the additional generation mentioned above. Map No. 594-400-79 is attached hereto as Figure 1 to show the CRSP powerplants and transmission facilities, as well as other existing principal power systems in the market area. IV. HISTORY OF TRANSMISSION RATES The first CRSP firm transmission rate, $4.50 per kilowatt-year, was established in October 1965. The estimated transmission costs were $8,968,000 at that time, which were comprised of annual amortization and OM&R costs of the planned CRSP transmission system, plus estimated costs to the United States of wheeling over other systems in Utah. The estimated transmission capacity commitments were 1,986.5 MW, which consisted of 1,351.5 MW for the planned installed capacity of the CRSP plants, including the Central Utah Project plants, 600 MW for Colorado-Ute (Ute) and Salt River Project (SRP) and 35 MW for Navajo Tribal Utility Authority (NTUA). Dividing the cost of $8,968,000 by the capacity of 1,986,500 kW resulted in a unit cost of $4.51 which was rounded to $4.50 per kW-year for the established firm transmission rate. At an annual load factor of 58.2 percent the 'rate would be about 0.9 mills per kWh. A rounded figure of 1 mill per kWh was used as the nonfirm transmission rate. The firm transmission rate was raised to $6.60 per kW-year in May 1974. It was based on the average of the estimated annual costs per kilowatt for the years FY 1975, 1976, and 1977. The aforementioned 3-year , estimated average annual transmission costs were $10,453,000 as of May 1974, which were comprised of the annual amortization and OM&R costs of the CRSP transmission system expected to be in-service plus the estimated costs of wheeling over other systems, less estimated rental revenues due from others 7