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<br />Revenues to cover these increased costs are expected to come from: firm <br />power and energy sales (73%); fuel replacement (conservation) sales (14%); <br />transmission services (10%); and other sources (3%), including Hoover <br />defi ci ency reimbursements, rent a 1 of faci 1 i ti es, and mi sce 11 aneous. <br /> <br />The CRSP FY 1981 revised power repayment study indicated that the year <br />when the maximum repayment requirement occurred was in FY 2057, and that <br />year is therefore referred to as the rate-setting point. Storage unit <br />power revenues above those needed to pay annual costs and to repay storage <br />unit investment costs must be apportioned to repayment of participating <br />'project costs in the four Upper Basin states according to the formula in <br />Public Law 84-485. Thus, the repayment requirements for a particular <br />project or projects in one state, ,in this case the requirements for the <br />Central Utah Project in Utah by FY 2057, governs the amount of assistance <br />needed from power revenues, and results in collecting revenues for <br />projects in other states in excess of currently authorized needs. <br /> <br />There are presently no definite schedules for construction of the' <br />Fruitland Mesa, LaBarge, San Miguel, Savery-Pot Hook, and West Divide <br />participating projects, and yet these projects are not deauthorized. For <br />purposes of the repayment studies, Western has assumed that construction <br />of these projects would start sometime in the 2020 through 2030 period, <br />and that initial water service would be in FY 2031. Thus, assistance from <br />CRSP power revenues for repayment of these projects does not affect the <br />power rate needed, since such revenues would not be needed until sometime <br />after FY 2057, the rate-setting point. The assumed water depletions <br />starting in FY 2031 for these projects do affect the power rate needed. <br />However, it appears reasonable to assume that, if the five participating <br />projects without definite schedules are not constructed, other uses for <br />the water will develop by FY 2031. <br /> <br />Published procedures for public involvement in proposed rate adjustments <br />will be followed. Interested persons may consult with and obtain <br />information from Western representatives. <br /> <br />Western will prepare an environmental evaluation of the proposed rate <br />adjustment and will send copies to interested persons upon request. <br /> <br />II. RATE ADJUSTMENT PROCEDURE <br />A. Announcement of Proposed Rates and Consultation and Comment <br />Period. On Aprl I 30, 1982, an advance announcement was made at a CRSP <br />customer meeting in Salt Lake City, Utah, that a power rate adjustment was <br />being considered, and that a preliminary study indicated the firm power <br />rate would need to be increased from the present rate of 7.89 to about 10 <br />mills per kWh at 58.2 percent seasonal load factor. The procedures <br />adopted by the Department of Energy for transmission and power rate <br />adjustments give interested persons a reasonable opportunity for <br />participation in the development of the rates. The first step required by <br />the procedure is the issuance of a Federal Register notice and <br />distribution of this brochure, announcing the proposed transmission and <br />firm power rates and the criteria used in determining the rates. A pUblic <br />consultation and comment period starts with the date of the Federal <br />Relister notice and ends 90 days thereafter. During this period, <br />1n erested <br /> <br />3 <br />