Powering Europe - European Wind Energy Association
Powering Europe - European Wind Energy Association
Powering Europe - European Wind Energy Association
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annex<br />
fiGURE 19: lonG-tERM MaRGinal Costs foR Coal-fiRED anD Gas-fiRED Plants in GERMany 2020<br />
166<br />
€/MWh<br />
70,0<br />
60,0<br />
50,0<br />
40,0<br />
30,0<br />
20,0<br />
10,0<br />
0,0<br />
Natural Gas<br />
to prices). The demand data input above is given exogenously.<br />
The model then calculates the actual demand<br />
in accordance with specified income and price<br />
elasticity 19 .<br />
Investments<br />
In both scenarios, wind and other renewable capacities<br />
are fixed, as described on page 142. But the Classic<br />
Carbon model contains a module that generates<br />
investments in electricity capacity based on the gap<br />
between supply and demand.<br />
Hence, if the exogenous given capacity development is<br />
not sufficient to meet power demand, the model would<br />
determine the additional investments needed endogenously.<br />
The general logic behind endogenous investment<br />
decisions is that if the price of electricity exceeds<br />
the long-term marginal cost of the least expensive conventional<br />
technology, there will be investment in this<br />
technology. The overall costs of each technology depend<br />
on the technology’s capital costs, fuel costs, efficiency,<br />
CO2 costs, fuel transport costs and other variable<br />
Generation volumes<br />
Coal<br />
Capital cost<br />
Fixed O&M<br />
Non fuel variable cost<br />
Fuel and transport cost<br />
CO2-price<br />
and fixed costs. Investments are, subject to restrictions,<br />
usually made in coal-fired or gas-fired capacity.<br />
However, conventional investments are restricted in<br />
two main aspects. First, the model restricts endogenous<br />
investments in nuclear, as developments in<br />
these technologies tend to be influenced to a large degree<br />
by politics. Second, the potential investment levels<br />
and investment technologies are capped for each<br />
country according to the existing capacity profile so<br />
that the model cannot define unlimited investments in<br />
only one technology.<br />
Figure 19 compares the assumed long-run marginal<br />
costs for new CCGT and new coal-fired capacity for Germany<br />
in 2020. The figure is based on the assumption<br />
that a CCGT unit is run with an availability of 85% whereas<br />
a coal condensing unit is run with a slightly higher<br />
availability, 90%. 20 With the applied assumptions, coal<br />
is the least-costly technology in 2020. As fuel transportation<br />
cost is the only component that varies between<br />
the countries, it can be deduced that most capacity investments<br />
in Western <strong>Europe</strong> generated by Classic are<br />
in coal capacity, given the fuel and CO2 prices that the<br />
19 price elasticities are an expression for a percentage change in demand following a percentage change in price. For example, if<br />
demand drops by 0.5% following a 1% price increase, the price elasticity equals 0.5. The elasticity is therefore a measure for how<br />
flexible (or sensitive) the demand is with respect to price changes.<br />
20 The availability of a condensing unit in the classic model is a model result and could thus deviate from the assumptions in above figure.<br />
<strong>Powering</strong> <strong>Europe</strong>: wind energy and the electricity grid