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 />
energy, including the electricity, will presumably not differ much from the cost of gasoline or<br />
diesel fuel in ten years from now. It remains to be seen to what extent V2G is to be preferred<br />
over large-scale electricity storage options, or whether it should be seen instead as an ultimate<br />
resource to avoid black-outs in very rare occurrences. 2 One can assume, though, that the<br />
required storage capacities are driven much more by the constraints of responding to peak<br />
demand than by the constraints of avoiding curtailment of renewable variables.<br />
Large-scale electricity storage<br />
Technology options for electricity storage are examined in Chapter 3. The primary candidate<br />
for very large-scale electricity storage is pumped-hydro. The power capacity of some existing<br />
plants might be increased through more frequent use of their existing reservoir capabilities.<br />
But many new stations would be necessary to fulfil the storage requirement of a high<br />
penetration of variable renewables.<br />
The overall potential offered by natural relief is not precisely known, and not all countries<br />
have mountains, but it is probably much larger than the current capacities. Many existing<br />
hydropower stations, sometimes already consisting of several successive basins, could be<br />
turned into pumped hydro stations. In North America, for example, with 100 metres altitude<br />
difference, the lakes Erie and Ontario could provide for 10 GW peaking capacities and very<br />
large storage capacities due to their large surface areas. They could offer one of the few<br />
affordable seasonal storage options, providing the investment in waterways and pumps/<br />
turbines is paid for by daily operations.<br />
New options are also emerging that would allow pumped-hydro stations using the sea as the<br />
lower reservoir. One such pilot plant is already in service in the Japanese island of Okinawa<br />
(Photo 11.1). Seawater pumped-hydro facilities could be built in many places. Ideally<br />
situated sites would allow for a water head of several dozen metres difference between a cliff<br />
top basin and sea level.<br />
If mountainous and coastal natural-lift pumped-hydro plants were not sufficient, it is possible<br />
to build new plants on the sea, entirely offshore or, more likely, coastal, as this would limit<br />
the length of the necessary dykes. The idea is to use dykes to create a basin (Figure 11.7) that<br />
is either higher or lower than sea level. The necessarily low water head in such cases,<br />
however, would require large water flows. In total the costs for very large seawater plants<br />
might be 50% higher than in the cases described earlier, and even higher for smaller plants.<br />
Economies of scale are important here, as the storage capacity increases with the square of<br />
the dyke lengths, which account for a large share of the costs. Although no such plant exists<br />
yet, the concept involves no more than a combination of existing marine technologies.<br />
Resistance to corrosion from salty waters, in particular, has been proven for half a century<br />
with tidal plants such as La Rance in France.<br />
Because use of pumped-hydro storage to manage variable renewable sources is based on<br />
daily operations, it offers a much smaller footprint than ordinary hydro power of similar<br />
electric capacities. A global capacity of 2 500 GW pumped-hydro storage for 50 hours would<br />
require (assuming standard depths for the basins) less than 40 000 km 2 of surface area,<br />
compared to 300 000 km 2 for existing hydropower plants.<br />
2. See Jacobson and Delucchi, 2011b for an extensive discussion of the costs of V2G.<br />
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© OECD/<strong>IEA</strong>, 2011