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. CRSP Glen Canyon Powerplant Flaming Gorge Powerplant Curecanti Unit Blue Mesa Powerplant Curecanti Unit - Morrow Point Powerp1ant Curecanti Unit - Crystal Powerplant Subtotal MW 950 008 60 The Flaming Gorge Powerplant went on the line in November 1963, followed by the Glen Canyon Powerplant in September 1964. On the Curecanti Unit, the Blue Mesa Powerplant went on the line in September 1967, the Morrow Point Powerplant in December 1970, and the Crystal Powerplant in August 1978. The Fontenelle Powerplant of the Seedskadee participating project went on the line in May 1968. Following are the presently installed hydroelectric nameplate generating capacities. UO 28 1,266 Participating Projects Seedskadee Project - Fontennelle Powerplant Grand Total 10 1,276 A future power development expected to be in service by 1982, is the 23 MW plant of the Navajo Indian Irrigation participating project, which will be installed below the CRSP Navajo Dam. In about 1989, the 133.5 MW of the three potential plants of the Central Utah participating project are expected to be placed in service. Addition of the aforementioned plants will bring the total installed capacity to 1432.5 MW. Power generated at the CRSP and participating projects is dedi- cated 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: a Northern Division comprised of the states of Colorado, New Mexico, Utah, Wyoming, and part of Nevada; a Southern Division comprised of Arizona and parts of the states of Nevada and California. Power was sold initially to preference customers up to their total requirements with the provision that power would be with- drawn from Southern Division customers as Northern Division loads develop, until a sale to the Southern Division was reached amounting to 20 percent of project capability in the summer and 7 percent in the winter. These percentages then became the maximums for future years for sales to Southern Division customers. Since April 1976, the maximum seasonal load factor permitted has been 58.2 percent, because of the desire to limit firming energy purchases. In addition, the policy was adopted in February 1978, as announced in the Federal Register, that Crystal power and other future power made available by higher reservoir water levels or by additional power generating facilities would be sold as peaking power, i.e., sales of capacity without energy. 5