Capacity Utilization and Shares of New RPS Capacity

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... highest wind capac- ity factor is in Colorado followed by Pennsylvania, New Mexico, Wisconsin, and Oregon. Also, reported in Table 7 are the shares of new capacity supplied by wind for each state. These shares are determined based upon recent and planned mix of renewable ca- meeting RPS goals in Colorado, New Mexico, Oregon, The levelized costs for wind power appears in Table costs are assumed to decline 0.3 percent annu- costs by slightly more than 7.7 percent over the forecast horizon. ...

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... shares are determined based upon recent and planned mix of renewable ca- meeting RPS goals in Colorado, New Mexico, Oregon, The levelized costs for wind power appears in Table costs are assumed to decline 0.3 percent annu- costs by slightly more than 7.7 percent over the forecast horizon. The levelized costs for solar photovoltaic genera- where p isl - struction costs, OMsl and maintenance costs, K sl sl is the investment tax credit of 30 percent, and the capacity factors, U isl , are reported in Table 7 based upon data most new renewable capacity is supplied by solar in some eastern states, such as Delaware, the Carolinas, and Virginia. ...

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... Table 7 indicates slightly over 55 percent of new RPS capacity for Colorado is assumed to come from wind power with the remainder supplied by new solar generating plants. New RPS wind and ...

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... RPS goals and the extension of those goals to increase the share of renewable energy to RPS goals reduce the need for additional new NGCC up until 2025. For instance, in the base case with- out additional RPS capacity, new NGCC capacity (MW) and with RPS incremental NGCC capacity de- As Table 7 indicates slightly over 90 percent of new RPS capacity for Delaware is assumed to come from solar power with the remainder supplied by new wind generating plants. New RPS solar and wind - spectively in 2025. ...

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... RPS goal for Utah is 20 percent of total con- sumption by 2025. The impacts on electricity mar- - ed in Table 70. The RPS goals reduce the need for additional new NGCC as these goals are met. ...

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... RPS goals reduce the need for additional new NGCC as these goals are met. For instance, in the base case without additional RPS capacity, new NGCC capacity required to balance the RPS there is no new NGCC capacity required in 2020 (see Table 70). ...

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... solar and solar - tively in 2025. The electricity generation from these generation is 0.5 million MWh (see Table 70). ...

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... increases in average electricity costs from new (see Table 70). With legacy costs average electric- - goals of 20 percent and an existing generation base dominated by low-cost coal generation. ...

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... following two sub-sections summarize the impacts of existing and future RPS goals on the elec- - ment in Virginia. The decomposition of RPS costs for the Virginia electricity sector appears in Table 77. Net RPS lega- cy costs are zero because there is no existing wind and solar capacity in Virginia. ...

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... RPS lega- cy costs are zero because there is no existing wind and solar capacity in Virginia. The costs associated adding new RPS capacity to reach the RPS goals also appear in Table 77. The direct costs to achieve years (see Table 77). ...

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... costs associated adding new RPS capacity to reach the RPS goals also appear in Table 77. The direct costs to achieve years (see Table 77). After adding cycling costs and deducting for fossil fuel and NGCC capacity costs, the net costs to bring meet the RPS goal are $534 - (see Table 77). ...

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... direct costs to achieve years (see Table 77). After adding cycling costs and deducting for fossil fuel and NGCC capacity costs, the net costs to bring meet the RPS goal are $534 - (see Table 77). The RPS policies in Virginia reduce carbon dioxide - lion tons per year by 2040 (see Table 77). ...

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... adding cycling costs and deducting for fossil fuel and NGCC capacity costs, the net costs to bring meet the RPS goal are $534 - (see Table 77). The RPS policies in Virginia reduce carbon dioxide - lion tons per year by 2040 (see Table 77). The direct - $42 per ton in 2040. ...

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... impacts of higher electricity prices are and remain over $2.5 billion per year out to 2040. - ployment in the base case without renewable en- ergy portfolio standards after 2020 (see Table 79). These losses from higher electricity prices are par- tially offset by output and employment gains from building and operating electricity capacity needed to meet RPS goals. ...