Solar Energy Perspectives - IEA
Solar Energy Perspectives - IEA
Solar Energy Perspectives - IEA
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Chapter 2: The solar resource and its possible uses<br />
those where much of the increase in energy demand is expected to take place in the<br />
coming decades.<br />
By separating the direct and diffuse radiations, it is clear that direct sunlight differs more than<br />
the global resource. There is more diffuse irradiance around the year in the humid tropics,<br />
but not more total energy than in southern Europe or Sahara deserts (Figure 2.8).<br />
Arid areas also exhibit less variability in solar radiation than temperate areas. Day-to-day<br />
weather patterns change, in a way that meteorologists are now able to predict with some<br />
accuracy. The solar resource also varies, beyond the predictable seasonal changes, from year<br />
to year, for global irradiance and even more for direct normal irradiance. Figure 2.9 illustrates<br />
this large variability in showing the global horizontal irradiance (GHI) in Potsdam, Germany<br />
(top), and deviations of moving averages across 1 to 22 years (bottom). One clear message is<br />
that a solar device can experience large deviations in input from one year to another. Another<br />
is that a ten-year measurement is needed to get a precise idea of the average resource. This<br />
is not measurement error – only natural variability.<br />
Tilting collectors, tracking and concentration<br />
Global irradiance on horizontal surfaces (or global horizontal irradiance [GHI]) is the<br />
measure of the density of the available solar resource per surface area, but various other<br />
measures of the resource also need to be taken into account. Global irradiance could also be<br />
defined on “optimum” tilt angle for collectors, i.e. for a receiving surface oriented towards<br />
the Equator tilted to maximise the received energy over the year.<br />
Tilting collectors increases the irradiance (per receiver surface area) up to 35% or about<br />
500 kWh/m 2 /y, especially for latitudes lower than 30°S and higher than 30°N (Figure 2.10).<br />
The optimal tilt angle is usually considered to be equal to the latitude of the location, so the<br />
receiving surface is perpendicular to the sun’s rays on average within a year. However, when<br />
diffuse radiation is important, notably in northern Europe and extreme southern Latin<br />
America, the actual tilt angle maximising irradiance can be up to 15° lower than latitude. The<br />
economically optimal tilt angle can differ from the irradiance optimised tilt angle, depending<br />
on the type of application and the impact of tilt angles on the overall investment cost.<br />
Other potentially useful measures include the global irradiance for one-axis tracking surface<br />
and the global irradiance for two-axis tracking surface. This defines the global normal<br />
irradiance (GNI), which is the maximum solar resource that can be used. Direct irradiance is<br />
more often looked at under the form of direct normal irradiance (DNI) – the direct beam<br />
irradiance received on a surface perpendicular to the sun’s rays.<br />
The respective proportions of direct and diffuse irradiance are of primary importance for<br />
collecting the energy from the sun and have many practical implications. Nonconcentrating<br />
technologies take advantage of the global radiation, direct and diffuse<br />
(including the reflections from the ground or other surfaces) and do not require tracking.<br />
If sun-tracking is used with non-concentrating solar devices, it need not be very precise<br />
and therefore costly, while it increases the amount of collected solar energy. It allows<br />
taking advantage of the best possible resource. This is worthwhile in some cases, but not<br />
that many, as expanding a fixed receiver area is often a less costly solution for collecting<br />
as much energy.<br />
39<br />
© OECD/<strong>IEA</strong>, 2011