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>: Policies<br />
So far most of the rapid growth of PV has taken place in a very limited number of markets,<br />
all driven by FITs. Germany, Spain, Italy and the Czech Republic account for over 60% of<br />
global capacity (Figure 3.1). About half of global capacity is in Germany alone.<br />
Generous incentives, inconsistent with declining PV costs, have been and still are available<br />
in several countries. This has encouraged intermediaries to appear in the PV development<br />
business, since projects allow for relatively high returns. Final investors harnessed<br />
reasonable returns, while intermediaries captured excessive rewards. While the market<br />
recognised how PV costs have been dropping sharply, regulation often did not follow<br />
a similar path. Potential market changes were not considered at the start and remuneration<br />
levels remained too high.<br />
Difficulties began in Spain in 2008, when installed capacity reached 4 GW, almost<br />
10 times more than the official target at that time. Since 2009 drastic future PV<br />
remuneration cuts have been enforced (-70% of 2008 tariffs), further reductions<br />
programmed, and what industry claims as retroactive regulation applied. 3 Also relatively<br />
high new targets are defined for 2020 (8.4 GW). These adjustments have undermined<br />
investors’ confidence.<br />
In Italy, PV accelerated in 2010, with 3.1 GW cumulative capacities in 2010 and 4 GW<br />
awaiting connection, according to GSE, the public renewables institution. If all this capacity<br />
is connected, 87% of the 2020 targets will be met already by 2011. The Czech Republic and<br />
France have experienced similar unexpected outcomes. Greece may be next, with one of the<br />
most generous FITs in Europe, very good sunshine, and more than 5.3 GW of applications<br />
for PV capacities towards a 2020 target of 2.2 GW. A target of 10 GW by 2025 was set in<br />
early September 2011, mostly for exports to Germany. Last but not least, in Germany, where<br />
some 8.5 GW were installed in 2010, the growth rate still exceeds that which would be<br />
consistent with the 2020 targets (about 3.6 GW/y).<br />
The German FIT, after several revisions and adjustments, is probably the most sophisticated<br />
to date. In 2008 a “corridor system” was introduced that ties the rate of regression in support<br />
level to the recent rate of investments. Despite this, three non-scheduled decreases in support<br />
levels were introduced in 2010 and 2011. They have considerably helped keep the FIT<br />
levels – more precisely, the net present value of all future payments – quite close to actual<br />
PV costs in Germany (Figure 10.4), which due to market maturity are significantly lower than<br />
in sunnier countries. It remains to be seen, however, whether both scheduled and nonscheduled<br />
tariff decreases have provided German policy makers with the greater level of<br />
control on total costs passed on to electricity end-users they were seeking. The most recent<br />
information is encouraging, as PV systems commissioned between March and May 2011 in<br />
Germany were about 700 MW, likely to lead to a yearly increase of 2.8 GW, much closer to<br />
target than in 2010.<br />
Cost control appears especially difficult in the case of PV. PV is extremely modular, easy and<br />
fast to install and accessible to the general public. 288 000 installations of less than 100 kWp<br />
were installed in Germany over 12 months (Figure 10.5) – almost three times the cumulative<br />
3. The number of full-capacity hours at which the tariff is paid was limited. Investors having PV systems that are oversized in relation<br />
to their rated and contractual capacities are likely to be hardest hit.<br />
182<br />
© OECD/<strong>IEA</strong>, 2011