Solar Energy Perspectives - IEA
Solar Energy Perspectives - IEA
Solar Energy Perspectives - IEA
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<strong>Solar</strong> <strong>Energy</strong> <strong>Perspectives</strong>: Testing the limits<br />
renewable electricity in the system, it drops to about USD 19/MWh, and USD 13/MWh with<br />
respect to the overall electricity generation (out of CSP-suitable zones).<br />
Sound economic decisions, however, focus on marginal costs, i.e. the cost of each additional<br />
PV or wind power kWh, which must be made dispatchable in systems with already large<br />
penetration of renewable, and bear the cost of storage. In sunny regions with more PV than<br />
STE/CSP, USD 19/MWh of storage will add to a cost of electricity from PV of less than USD<br />
70/MWh (after 2030). In cold countries, as wind power dominates the mix, the cost of<br />
electricity storage will be borne by wind power, and the sum of both costs will remain close<br />
to the USD 100/MWh mark.<br />
Other technologies for large-scale electricity storage are compressed-air electricity storage<br />
(CAES) and advanced-adiabatic CAES (see Chapter 3). Their deployment first rests on the<br />
availability of underground caves suitable for this use. Some analysts assume that large<br />
capacities are available (Fthenakis et al., 2009; Delucchi & Jacobson, 2011a and b), and<br />
suggest CAES and AA-CAES will be the key to integrating large amounts of variable electricity<br />
in future grids. However, they have not provided evidence for why these options should be<br />
preferred over pumped-hydro storage, apart maybe from an implicit preference for storage on<br />
the sites of PV or wind power generation.<br />
Footprint of solar electricity<br />
The projected PV capacity in our future “big picture”, initially estimated at 12 000 GW,<br />
needs to be increased to 15 300 GW to compensate for half the losses in electricity storage<br />
(the other half being compensated by wind power). With an average efficiency of 15% and<br />
average peak solar irradiance of 1 kW/m 2 , this capacity would represent a total module<br />
surface area of 100 000 square kilometres. Obviously not all modules would find a space<br />
on building roofs and even with many other supporting structures ground-based PV systems<br />
will be needed, possibly for two-thirds of the modules. With an appropriate tilt the required<br />
surface area, although not necessarily unavailable for other uses, increases by a factor 1.7<br />
at mid-latitudes. The total surface area would thus be 115 000 km 2 .<br />
Apart from rooftops, parking lots, farms and other structures, considerable potential rests in<br />
“brownfields”, i.e. areas that have been severely impacted by former industrial activities,<br />
whose re-use options are limited by concerns for public health and safety. The US<br />
Environmental Protection Agency runs a “brownfields program”, siting renewable energy on<br />
contaminated land and mine sites. It tracks approximately 490 000 such sites covering about<br />
60 000 km 2 .<br />
Another intriguing option is to develop floating PV plants. Such plants could have an<br />
increased efficiency with easy one-axis tracking – by simply rotating large floating structures<br />
(one revolution per day) supporting PV systems. Projects of this sort are already being<br />
considered, in particular on artificial or natural lakes feeding hydro power plants, where they<br />
would benefit from existing connecting lines, and would benefit the hydro plants by limiting<br />
evaporation. Sceptics, however, point out the cost of floating support structures.<br />
STE/CSP is more efficient than PV per surface of collectors, but less efficient per land surface,<br />
so its 25 000 TWh of yearly production would require a mirror surface of 100 000 square<br />
kilometres and a land surface of about 300 000 km 2 . These areas will, however, be easier to<br />
find in arid regions with low or very low population densities and little agricultural activity.<br />
208<br />
© OECD/<strong>IEA</strong>, 2011