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 />
starting with the lowest-price offer, moving up to more expensive options until demand is<br />
met. Under normal conditions, the offer price of the last unit of generation dispatched (the<br />
“marginal” unit of generation) sets the market price for electricity, which is paid for all<br />
generation dispatched irrespective of their individual offers (giving birth to what is called<br />
“infra-marginal rents”).<br />
Perhaps counter-intuitively, nuclear and renewable generators can be more exposed to fuel<br />
and carbon price uncertainty than fossil-fuel generators under marginal pricing. A gas-fired<br />
combined-cycle plant that sets the marginal price will generally recover its operating costs<br />
(including fuel and carbon), because the electricity price adjusts to cover these costs. It will<br />
also benefit from higher prices during peak periods to recover its modest capital costs.<br />
Ultimately, the gas-fired generators’ profits are not strongly exposed to fluctuations in the<br />
price of gas or carbon, as long as the generation is setting the marginal price.<br />
Conversely, the profitability of a plant that has high capital investment costs but very low<br />
short-term running costs (such as a nuclear or renewables) is strongly exposed to uncertainty<br />
in gas or carbon prices, as these set the market price of electricity, and hence determine the<br />
revenue available to cover these plants’ high capital costs (Figure 10.7).<br />
Figure 10.7 Schematic of profit variability from electricity generation<br />
Cost/price<br />
Gas plant<br />
Average<br />
spot price<br />
Generation<br />
costs<br />
(fuel, carbon,<br />
capital<br />
repayments)<br />
Profit<br />
Renewable or nuclear plant<br />
Cost/price<br />
Time<br />
Time<br />
Source: <strong>IEA</strong>, 2011f.<br />
Key point<br />
Fuel cost variability is a bigger concern for non-fossil renewables generators.<br />
This raises the question of whether current electricity market designs make investment in<br />
low-carbon technologies, which typically have high up-front capital costs, riskier than<br />
continued investment in fossil-fuel plants. This elevated risk could deter investment in lowcarbon<br />
generation, even where carbon pricing or other policy interventions have made it<br />
cost-effective. At present, long-term fixed payments, whether from FITs or RPS-driven PPAs,<br />
are required to shield project developers from this profit uncertainty. To a lesser extent, FIPs<br />
and RECs markets also reduce the economic risks.<br />
Current market designs based on marginal pricing also have important effects when large<br />
shares of renewable electricity are introduced. There are increasingly times during which<br />
188<br />
© OECD/<strong>IEA</strong>, 2011