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irradiance levels are above a certain design value in this case 750 W/m2. This calculation was done in two ways. The first way was by visual inspection of the solar irradiance charts. This methodology facilitated the exclusion of brief intermittent cloud cover. During these brief periods there would not be much effect on the amount of energy supplied to the power system. The opposite is also true. When there are long periods where irradiance levels are below designed requirements, it will take time for the heat transfer fluid to be reheated. Irradiance measurements were taken in Newcastle, UT starting in the middle of November 2011 (37.658429 North 113.571087 West). Figures 22 through 25 are plots of these measurements. Each plot is followed by a brief description of how the adequate irradiance time was estimated. The GHI and DHI were measured and the DNI calculated. Figure 22 shows a sunny day in Newcastle, UT. The global and diffuse measurements are nearly the same from 7:30 am until 8:15 am which makes the calculation of the direct irradiance slightly inaccurate. Recognizing this difficulty, visual inspection was assumed to indicate that irradiance levels reached 750 W/m2 at 8:00 am. From 10:30 am to 11:00 am, the global irradiance levels almost match the diffuse values. This was due to a telephone pole located to the south of the solar station. When doing a visual inspection, such consistent irregularities could be ignored. It also appears that there may have been some cloud cover at 12:30 pm which could also be ignored since the heat transfer fluid in the solar troughs would still be at the temperature required by the power system over this short period of time. This day was allocated seven and one half hours of time when irradiance levels were above 750 W/m2. 49PDF Image | WORKING FLUID SELECTION FOR AN INCREASED EFFICIENCY HYBRIDIZED GEOTHERMAL-SOLAR THERMAL POWER PLANT IN NEWCASTLE, UTAH
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