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 />
considered to be excessive (<strong>IEA</strong>, 2008d; <strong>IEA</strong>, 2011h ). It shows no general superiority of one<br />
system over others. This underlines the importance of the non-market barriers that may stand<br />
in the way of effective deployment, and the need to design specific policy measures to<br />
overcome them.<br />
RECs markets are usually considered better suited to more mature technologies than to<br />
emerging ones. Even for a mature technology like wind, however, several countries with<br />
RECs systems reportedly intend to move in the next few years towards FITs (UK) or tenders<br />
(Italy), to reduce system costs (but the Netherlands may go the other way, moving from FITs<br />
to RPS).<br />
While FITs have been criticised as providing investors with weak stimulus to reduce costs due<br />
to very stable cash-flow perspectives, this may have finally turned into an advantage as<br />
reducing investors’ risks allowed reducing the costs of capital. As up-front investments<br />
represent the bulk of the cost of renewables, the cost of capital to utilities or developers has<br />
a direct and important bearing on the levelised cost of electricity. Emerging technologies<br />
usually bear some technology risks; they can hardly bear large market risks at the same time,<br />
which in the case of solar electricity arise from the volatility of fossil fuel prices, as shown<br />
below. A secure framework reduces the costs of capital, and thus the cost of solar energy. For<br />
this reason, RPS work more effectively if they drive utilities to offer long-term, stable PPAs to<br />
solar project developers.<br />
However, FITs do not by themselves offer policy makers easy control over the policy costs,<br />
a legitimate preoccupation. FITs or FIPs control the level of incentives but not the amount of<br />
investments made – as the regulator does not accurately know the rapidly changing<br />
technology costs. RPS control the investment, but not the incentive level, for the same reason.<br />
Tenders could in theory provide a solution to the dilemma but are less suitable for small-scale<br />
projects and do not necessarily deliver large projects when aggressive bidding drives<br />
remuneration levels too low.<br />
Most systems in practice mix elements of price control and quantity control. For example,<br />
most RPS with solar set-asides also have solar-specific alternative compliance payments<br />
(SACP), setting an upper limit for the cost of RPS solar compliance. This also serves to cap<br />
prices for all RECs in the entire RPS. Another approach is the Spanish FIP for STE/CSP<br />
plants, which is only valid for a yearly total aggregate capacity (500 MW) of newly-built<br />
plants.<br />
Feed-in tariffs and feed-in premiums<br />
FITs or FIPs have demonstrated efficacy in the absence of strong non-economic barriers, but<br />
are not necessarily cost-effective. Further, even if cost-effective, they do not offer policy<br />
makers an easy control over total costs, i.e. they can prove “too effective” in driving<br />
investments beyond or faster than expectations.<br />
Generous incentives, inconsistent with declining PV costs, have been and still are available<br />
in several countries. This might be necessary to jumpstart a new activity by providing<br />
potential investors with attractive returns. However, sustained high-level support is<br />
inconsistent with declining PV cost and encourages intermediaries to appear in the PV<br />
development business. FITs and FIPs are usually paid by electricity customers (ratepayers)<br />
180<br />
© OECD/<strong>IEA</strong>, 2011