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<br />I <br />I <br />I <br />I <br />I <br />I <br />I <br />I <br />I <br />I <br />I <br />I <br />I <br />I <br />I <br />I <br />I <br />I <br />I <br /> <br />2.2 Data Collection <br /> <br />Each of the Colorado utility systems was modeled for a benchmark year (1986), and <br />the 20-year study period. Stone & Webster collected detailed data including load <br />forecasts, generation resources, and economic and financial parameters on a <br />confidential basis and input the data into the EGEAS model. These data categories <br />are discussed below on a statewide basis. <br /> <br />2.2.1 Load Forecasts <br /> <br />From 1980 to 1987, average annual load growth in the state has been approximately <br />2.6 percent for the utilities' summer peaks and 2.5 percent for the winter peaks. Per <br />TSC input, Colorado annual load growth is expected to be approximately 2.1 percent <br />for peak load and 2.2 percent for energy during the next 20 years. <br /> <br />The peak load and energy growth rates used in the study for the medium load growth <br />cases are presented annually for the peak demand for summer and winter, and for <br />total energy requirements on Table 2-1. <br /> <br />2.2.2 Generation Resources <br /> <br />The existing generation resources in the state are primarily coal-fired units, with a <br />small amount of run-of-river hydro, pumped storage and oil- and natural gas-fired <br />steam and combustion turbine (~T) units. The utilities have contracts among <br />themselves to buy and sell available capacity and spot energy available in Colorado <br />and adjacent states. Several utilities share ownership of certain units. <br /> <br />2-4 <br />