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<br />. <br /> <br />minor changes in estimates for annual generation from Collbran and Rio <br />Grande, and exclusion of Provo River generation. Because of the <br />increase in marketable firm capacity and the minor decrease in <br />marketable firm energy, the overall load factor has decreased from 52 <br />percent to 50.2 percent. <br />4. A purchase level of 400 GWh has been selected. <br />5. Allocation priorities have been clarified. <br />61 The Northern Division participating customer pool increased to <br />100 MW, an increase of 25 MW. <br />7. The Northern Division allocation method now includes <br /> <br />consideration of existing peaking power commitments in determining <br />allocations to existing customers. Southern Division existing <br />customer comments resulted in the selection of an allocation method <br />based ;on CRSP long-term power and all other Federal power resources <br />(Alternative No.3 in the 1984 Proposed Criteria). <br />8. A first right of refusal to the cities of Enterprise and <br />Hurricane, Utah, up to the remaining 50 percent of their 1975 summer <br />season: and 1976-77 winter season load requirements, has been granted <br />in the event power is available for reallocation. <br />9.' A Conservation and Renewable Energy (C&RE) Incentive Program <br />Pool of approximately 30 MW in each season has been created as a <br />direct result of decreasing reserve levels. The incentive program <br />pools will have load factors similar to pools for Northern Division <br />existing and participating customers. <br /> <br />7 <br />