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<br />. <br /> <br />3. The option to purchase 400 GWh was selected. All purchases <br />of finning power and energY would be on a pass-through-cost <br />basis. <br /> <br />4. CRSP marketable resources were reduced slightly for <br />additional priority uses, and amounts have been detennined <br />by the Bureau of Reclamation using a new hydrology model. <br />The new model resulted in an increase in the projected <br />annual energy of about 525 GWh. Additional resources may be <br />included prior to finalization of the plan, including about <br />130 MW which may be constructed with non-Federal funds. The <br />derivation of the SLCA Integrated Project's marketable <br />resources is explained in Appendix A. <br /> <br />5. The option to withdraw all CRSP in 1999 from the Southern <br />Division (S.D.) was not se1jected, but the proposed S.D. <br />conmitments from 1989-1999 have been adjusteff~roposed <br />~ --- ~ <br /> <br />commitments in the S.D. are based on about 17 percent <br />(summer) and about 10 perc~nt (winter) of 1200 MW to reflect <br />the intent of initial CRSPja11ocations, to reflect changes in <br /> <br />i <br />Northern Division seasonal : load diversity for new customers, <br />and to recognize a potential change in the availability of <br />Federal resources in the S.D. Required energy adjustments in <br />the S.D. would be made in ~ccordance with one of the <br />alternatives described and! demonstrated in an Appendix D. <br />This temporary appendix will be e1 iminated when an <br />alternative is selected and included in Appendix C. <br /> <br />6 <br />