Powering Europe - European Wind Energy Association

of 5.5 GW. The mean value corresponds to about 8%
of the installed wind power capacity, and the maximum
to 15.3%.
tablE 4: ChaRaCtERistiC fiGUREs foR winD PowER CaPaCity
anD GEnERation in 2003, 2009 anD 2015 basED on
sCEnaRios in thE DEna stUDy [DEna, 2005]
2003 2009 2015
installed wind power capacity (Gw) 14.5 25.8 36
annual wind energy generation (twh) 23.5 46.8 77.2
Effective capacity factor 18 % 21 % 25 %
wind energy share of annual electricity
demand (gross)
5.5 % 7.6 % 14 %
the realised values for 2009 are given for comparison.
tablE 5: oVERViEw of REqUiRED REGUlation PowER (Day
ahEaD REsERVE) in 2003 anD 2015 as foUnD in thE DEna
stUDy [DEna, 2005]
2003 2015
Average max Average max
Positive regulation capacity ( Mw) 1.2 2 3.2 7
% of wind power capacity 9 14 9 19
negative regulation capacity (Mw) 0.75 1.9 2.8 5.5
% of wind power capacity 5 14 8 15
installed wind power capacity 14.5 Gw in 2003, and 36
Gw in 2015. these capacities (primary and secondary
reserves) have to be scheduled to cope with unforeseen
changes in wind power output with respect to the
schedules.
In a follow-up study, the potential for increased integration
of wind power through the creation of an intraday
market was investigated [FGE/FGH/ISET, 2007]. It
concluded that using an intra-day market has no particular
advantage given the specific prices for reserve
power, and the mean spot market price of €45/MWh.
chApTEr 3 powersystemoperationswithlargeamountsofwindpower
6.2 Nordic region
An estimation of the operating reserve requirement
due to wind power in the Nordic countries has been
discussed in earlier studies [Holttinen, 2005 and Holttinen,
2004]. The results are presented in Table 6.
• The increase in reserve requirements corresponds
to about 2% of installed wind power capacity at 10%
penetration and 4% at 20% penetration. For a single
country this could be twice as much as for the Nordic
region, due to better smoothing of wind power
variations at the regional level. If new natural gas
capacity was built for this purpose, and the investment
costs were allocated to wind power production,
this would increase the cost of wind power by
€0.7/MWh at 10% penetration and €1.3/MWh at
20 % penetration. For comparison, the retail price of
electricity for households in Denmark is more than
€250/MWh (2009).
• The increase in use of reserves would be about
0.33 TWh/year at 10% penetration and 1.15 TWh/
year at 20% penetration. The cost of an increased
use of reserves, at a price €5-15/MWh would be
€0.1-0.2/MWh of wind energy at 10% penetration
and €0.2-0.5/MWh at 20% penetration.
The additional balancing requirements in this case are
significantly lower than, for example, the Dena report
results. This is mainly due to two things: first, the area
of study is much larger covering the whole of the four
Nordic countries. This illustrates the advantages of
operating the Nordic power system as a coordinated,
integrated system. Secondly, the results are calculated
from the variability during the operating hour, so
forecast errors for wind power on longer timescales
are not taken into account. The parties responsible for
balancing in the Nordic power system have the opportunity
to change their schedules up to the operating
hour. This means that part of the prediction error can
be corrected when more accurate forecasts arrive.
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