Turbine Wake Model for Wind Resource Software
Turbine Wake Model for Wind Resource Software
Turbine Wake Model for Wind Resource Software
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EWEC 2006 <strong>Wind</strong> Energy Conference and Exhibition<br />
<strong>Turbine</strong> <strong>Wake</strong> <strong>Model</strong> <strong>for</strong> <strong>Wind</strong> <strong>Resource</strong> <strong>Software</strong><br />
Ole Rathmann, Rebecca Barthelmie, and Sten Frandsen,<br />
Risoe National Laboratory, Denmark<br />
1 INTRODUCTION AND BACKGROUND<br />
<strong>Wind</strong> resource software like WAsP [1, 2] needs models to estimate the power loss in wind farms<br />
due to the wind speed reduction in wakes from up-wind wind turbines in the wind farm.<br />
Rather simple - and there<strong>for</strong>e computationally fast - models have hitherto often been used, e.g. in<br />
WAsP where the Park model [3, 4] is implemented. The simplicity of the Park model is obtained<br />
by neglecting certain details in near-flow-field around a turbine rotor and by assuming the wakes<br />
to expand linearly with distance. Also, it assumes a very simplistic rule <strong>for</strong> the effect of wakesoverlap,<br />
i.e. when wakes originating from different upwind turbine overlap at the position of the<br />
rotor of a downwind turbine.<br />
A number of attempts have been made to establish more accurate wake models from firstprinciple<br />
considerations. However, so far advanced and detailed wake models, even when<br />
including an explicit representation of turbulence and its impact on the wake expansion, have not<br />
been able produce convincingly better predictions [5].<br />
The present model, being based on the work by Frandsen et al. [6], aims at a wake description<br />
basically complying with first-principles and at the same time being simple by utilizing global<br />
conservation equations <strong>for</strong> volume and momentum. In contrast to the model by Frandsen et al.[6],<br />
where a regular grid-layout is assumed, the present model does not require any regularity of the<br />
wind farm layout. This last point is necessary if the model is meant to be used in connection with<br />
general wind resource software like WAsP.<br />
2 THEORY<br />
The two distinct regions of wakes behind wind turbines must be considered separately: the nearfield<br />
flow in the vicinity of a turbine rotor; and the region “far” downwind of the turbines, where<br />
the reduced wind speed in the wake(s) is wanted as the input flow <strong>for</strong> a downwind turbine.<br />
2.1 Near-field<br />
The near field may be described in terms of the following few properties, and as illustrated in<br />
fig.1.<br />
• The turbine thrust T, expressed in terms of thrust coefficient C T ;<br />
• The influence factor a, relating the wind speed U w0 immediately after the rotor to the free<br />
wind U 0 ;<br />
• The expanded flow area just immediately after the rotor, A w0 , related to the rotor area A R<br />
through the expansion coefficient β, which in turn is related to a<br />
• The total flow area expansion (from the stream-tube be<strong>for</strong>e to after the rotor) ΔA T :<br />
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EWEC 2006 <strong>Wind</strong> Energy Conference and Exhibition<br />
0.75<br />
0.5<br />
T<br />
= ρ C U (1)<br />
1 2<br />
2 T 0<br />
0.25<br />
0<br />
A R<br />
T<br />
A w0<br />
U<br />
= (1 − a)<br />
U (2); a= 1− 1− CT<br />
(3)<br />
w0 0<br />
-0.25<br />
U 0<br />
U w0<br />
A<br />
w0<br />
= β A (4)<br />
R<br />
1−<br />
1 2 a<br />
β=<br />
1−<br />
a<br />
(5)<br />
-0.5<br />
-0.75<br />
-2 -1 0 1 2<br />
Δ A = Aaβ (6)<br />
T<br />
R<br />
Figure 1. The near-field flow around a wind-turbine rotor.<br />
2.2 The far-field<br />
As illustrated in fig.2 one applies a cylindrical control volume aligned with the wind direction,<br />
containing all relevant turbines, and sufficiently wide, that one has vanishing speed deficit in the<br />
wind direction at the cylindrical surface.<br />
U 0<br />
U w<br />
(y, z)<br />
A<br />
Figure 2. Cylindrical control volume around a set of turbines. In fact, the control volume should<br />
include a cut-off at the ground level, but <strong>for</strong> graphical reasons this has been left out in the figure.<br />
By combining the volume and momentum balance equations <strong>for</strong> the control volume one finds that<br />
the flow field U w (y,z) at some downwind position must fulfill the following equation:<br />
1<br />
∑ Ti = ( , )( 0<br />
− ( , ))<br />
ρ<br />
∫∫ U<br />
A<br />
w<br />
y z U Uw<br />
y z dydz (7)<br />
i<br />
or expressed in terms of the relative speed deficit δ≡<br />
U<br />
w<br />
−U<br />
U<br />
0<br />
0<br />
(8):<br />
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EWEC 2006 <strong>Wind</strong> Energy Conference and Exhibition<br />
1<br />
2 ∑Ti<br />
= δ( , )( 1 −δ( , ))<br />
ρ<br />
∫∫ y z y z dydz (9)<br />
U<br />
A<br />
0 i<br />
Here the integration (y,z) is over the cross section of the exit area of the control volume.<br />
Frandsen [6] pointed out, that <strong>for</strong> a single wake one does not lose any essentials in the wake<br />
description by assuming a top-hat wake speed profile, although in reality the profile is probably<br />
Gaussian-like. We have adopted this idea and assume that within the wake boundary the wind<br />
speed deficit is constant, only depending on the downwind distance from the rotor from which it<br />
originates. We extended this assumption a bit more by also assuming the corresponding flow<br />
profile <strong>for</strong> a composite wake (consisting of a number of wakes originating from different upwind<br />
turbines): that the speed deficit distribution is mosaic-like, i.e. constant within each “tile” of the<br />
mosaic. This concept will be elaborated on in more detail below.<br />
2.3 Influence of turbulence.<br />
An explicit description of the interaction of the turbulence field and the wake expansion is<br />
believed to be possible, but it would require the establishment of a balance equation also <strong>for</strong> the<br />
turbulent kinetic energy. It is possible to set up such a balance equation where the turbine power<br />
and thrust determines the source terms at the turbine. However, such a balance equation will also<br />
involve the dissipation of kinetic energy, and presently the required relationship between mean<br />
flow, turbulence and turbulent dissipation within a wake is missing. Thus, it is not possible to fit<br />
an explicit treatment of turbulence within the scope of a simple wake model based on global<br />
balance equations. Instead the intention is to find out, how the wake expansion parameter(s) in<br />
the model described below can be made to depend on the thrust coefficient (viz. turbulence) and<br />
on the presence of interacting wakes.<br />
3 MODEL<br />
The wake-model consists of a sub-model <strong>for</strong> the downwind expansion of the wake, and a<br />
procedure to find the wind speed distribution in the wake at some position, the latter both in the<br />
case of the wake from a single turbine and in the case of a composite wake, consisting of a<br />
number of overlapping single wakes. For the composite wake, a procedure <strong>for</strong> finding the full<br />
“mosaic-tiles” speed distribution has been investigated, but a final solution procedure has not yet<br />
been established. Consequently, this mosaic-tiles sub-model is only sketched below. Instead, we<br />
have concentrated on the testing of a semi-linear approximation to the basic balance equation (9).<br />
3.1 <strong>Wake</strong> expansion<br />
Frandsen [6] originally proposed:<br />
1/ k<br />
⎡<br />
k /2 x ⎤<br />
Dw( x)<br />
= DR<br />
⎢β +α ⎥ with the expansion exponent 1/k = 1/2.<br />
⎣ DR<br />
⎦<br />
However, in a recent work, Barthelmie, Frandsen et al. [7] found experimental evidence from the<br />
Middelgrunden <strong>Wind</strong> Farm (see later) that the wake diameter measured far downwind tends to<br />
zero when extrapolated back to its originating turbine (x=0), and not to D . A value of α=0.7<br />
seemed to represent the measured data well. A modified <strong>for</strong>m of the wake-expansion equation<br />
was there<strong>for</strong>e was adopted to comply with this finding while still ensuring that the wake has the<br />
right initial diameter corresponding to eq.(4), and still using k=2:<br />
⎡ x ⎤<br />
Dw( x) = DR<br />
max ⎢β,<br />
α ⎥<br />
⎣ DR<br />
⎦<br />
1/2<br />
(10),<br />
3<br />
β 1 2<br />
R
EWEC 2006 <strong>Wind</strong> Energy Conference and Exhibition<br />
The wake area is thus:<br />
π<br />
A ( ) ( ( )) 2<br />
w<br />
x = Dw x − ACut − off<br />
(11)<br />
4<br />
where the last terms takes cut-off into account if the wake hits the ground surface.<br />
Now, each time a wake passes a turbine enshrouded within it, it must experience an expansion<br />
corresponding to the stream tube area expansion, ΔA T , ( eq.(6)). To take this into account we have<br />
modified the wake diameter model further as<br />
1/2<br />
⎡ x ⎤<br />
Dw( x) = DR<br />
max ⎢β,<br />
Γ+α ⎥ (12)<br />
⎣ DR<br />
⎦<br />
Here Γ is a dimensionless number, with a value of zero at x=0, and increasing in jumps every<br />
time a turbine is passed as<br />
A ( x, Γ+ΔΓ) −A ( x, Γ ) =Δ A (13)<br />
w w T<br />
The work by Frandsen et al. [6] indicates that the expansion coefficient α should vary with the<br />
thrust coefficient – in fact the indications go that it should be proportionally to it. However, in the<br />
present work the coefficient α is treated as a constant model parameter.<br />
3.2 Mosaic-tiles model<br />
The concept of the mosaic speed deficit distribution is illustrated in fig.3. For a mosaic wake<br />
speed distribution the balance equation (9) takes the rather complicated <strong>for</strong>m:<br />
1<br />
n<br />
n<br />
T = A δ (1 −δ ) (14)<br />
2 ∑ i<br />
( k) ( k) ( k)<br />
U 1 1 ( k )<br />
0 i =<br />
∑∑<br />
ρ J J J<br />
k = J<br />
A 1<br />
A 12<br />
A 123<br />
<strong>Wake</strong> 1 A 1<br />
A 123<br />
<strong>Wake</strong> 2<br />
A 12<br />
<strong>Wake</strong> 1<br />
<strong>Wake</strong> 2<br />
<strong>Wake</strong> 3<br />
<strong>Wake</strong> 3<br />
A 13<br />
Affected rotor<br />
Affected rotor<br />
Ground<br />
Ground<br />
Figure 3. Examples of overlapping wake “mosaic-tiles” configurations.<br />
Here J (k) denotes a tile associated with a certain sub-set of k wakes, and A and δ indexed with this<br />
symbol denotes the tile area and the relative speed deficit within the tile. E.g., when considering<br />
n=3 wakes, J (1) can take the values [1] , [2] and [3], while J (2) may take the values [1,2], [1,3],<br />
[2,3].<br />
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EWEC 2006 <strong>Wind</strong> Energy Conference and Exhibition<br />
3.3 Semi-linear model.<br />
In wake calculations, <strong>for</strong> a certain downwind turbine rotor, the relevant property is the mean<br />
value of the speed deficit over the rotor-plane area A RD :<br />
1<br />
<br />
A<br />
= ∫∫ δ( y, zdydz )<br />
(15)<br />
RD<br />
A<br />
ARD<br />
RD<br />
Now, the semi-linear model is based on the observation that <strong>for</strong> small speed deficits, δ«1, the total<br />
balance equation is linear in δ. This means that the contributions to the averaging integral from<br />
the different upwind turbines are additive in the sense, that one may consider the effect of each<br />
upwind turbine by itself, and then finally add up these contributions. This leads to the simple<br />
linear approximation:<br />
A<br />
() i<br />
1 [ Aw ( Δxi,<br />
D) ∩ARD]<br />
RD<br />
<br />
A<br />
≈ T<br />
RD 2 ( i)<br />
i<br />
ρ U0 i Aw ( Δ xi,<br />
D)<br />
∑ (16)<br />
() i<br />
Here [ Aw<br />
∩ A<br />
RD]<br />
indicates the overlapping area between the cross sectional area of wake no “i”<br />
and the area A RD of the considered rotor, while Δx i,D is the downwind distance from the turbine<br />
from which wake “i” originates.<br />
In order to get the exact solution of the total balance equation in case of only a single wake<br />
enshrouding entirely the downwind rotor, while having the same solution <strong>for</strong> multiple wakes in<br />
the limit of small speed deficits, we adopt the following approximation to be used in the semilinear<br />
model:<br />
A<br />
() i<br />
1 [ Aw ( Δxi,<br />
D) ∩ARD]<br />
RD<br />
<br />
A<br />
(1 − )<br />
RD<br />
A<br />
≈ T<br />
RD<br />
2 ( i)<br />
i<br />
ρ U0 i Aw ( Δ xi,<br />
D)<br />
∑ (17)<br />
4 COMPARISON OF SEMI-LINEAR MODEL WITH OFF-SHORE<br />
WIND FARM DATA<br />
The wake model has been tested against accessible wind farm data. As a basis, <strong>for</strong> the wake<br />
expansion coefficient a value of α =0.7 was used. However, as indicated in the figures, the<br />
parameter was in some cases varied to see if better agreement with data could be obtained in this<br />
way.<br />
4.1 Middelgrunden <strong>Wind</strong> Farm data<br />
<strong>Model</strong> predictions were compared to measured wind data from the Middelgrunden off-shore wind<br />
farm just east of Copenhagen. Two southerly wind directions were considered. The first direction<br />
(173°) was selected to be along the connection line between the two middle turbines, WT10 and<br />
WT11, to get maximum wake effect in the middle of the wind farm. The second one (186°) was<br />
selected to be along the connection line between the two southernmost turbines – WT20 and<br />
WT19 - to get maximum wake effect at the latter. These situations are both indicated in the figure<br />
4. The actual wind directions were measured by the yawing angle of the southern-most turbine<br />
(WT20), while the wind speeds were deduced from the turbine power productions.<br />
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EWEC 2006 <strong>Wind</strong> Energy Conference and Exhibition<br />
6180<br />
Northing (km)<br />
6179.5<br />
6179<br />
6178.5<br />
6178<br />
6177.5<br />
6177<br />
6176.5<br />
6176<br />
WT1<br />
WT2<br />
WT3<br />
WT4<br />
WT5<br />
WT6<br />
WT7<br />
WT8<br />
WT9<br />
WT10<br />
WT11<br />
WT12<br />
WT13<br />
WT14<br />
WT15<br />
WT16<br />
WT17<br />
WT18<br />
WT19<br />
WT20<br />
6175.5<br />
186 deg.<br />
173 deg.<br />
6175<br />
726 727 728 729 730 731 732<br />
Easting (km)<br />
Figure 4. “Middelgrunden <strong>Wind</strong> Farm” layout, with the Copenhagen shore-line indicated.<br />
The wind farm consists of 20 Bonus 2MW turbines with a rotor diameter of 76 m and a hub<br />
height of 67m. The spacing is about 2.4 rotor diameters. The arrows indicate the two wind<br />
directions investigated.<br />
Rel. <strong>Wind</strong> speed<br />
1.1<br />
1<br />
0.9<br />
0.8<br />
0.7<br />
0.6<br />
0.5<br />
0.4<br />
Alfa=0.7<br />
Meas.<br />
0 10 20 30 40 50<br />
Rel. Downwind Distance<br />
MG_173_9<br />
Free wind speed:<br />
9 m/s ± 0.5 m/s<br />
(62 sets of data)<br />
Figure 5. <strong>Wind</strong> direction 173°±1°. Relative distance in rotor-diameters.<br />
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EWEC 2006 <strong>Wind</strong> Energy Conference and Exhibition<br />
Relative <strong>Wind</strong> Speed<br />
1.1<br />
1<br />
0.9<br />
0.8<br />
0.7<br />
0.6<br />
0.5<br />
Alfa=0.7<br />
Meas.<br />
Free wind speed:<br />
6 m/s ± 0.5 m/s<br />
(48 sets of data)<br />
0.4<br />
0 20 40<br />
Relative wind speed<br />
1.1<br />
1<br />
0.9<br />
0.8<br />
0.7<br />
0.6<br />
0.5<br />
Alfa=0.7<br />
Meas.<br />
Free wind speed:<br />
9 m/s ± 0.5 m/s<br />
(37 sets of data)<br />
Relative <strong>Wind</strong> Speed<br />
0.4<br />
0 20 40<br />
1.1<br />
1<br />
0.9<br />
0.8<br />
0.7<br />
Alfa=0.7<br />
0.6<br />
Meas.<br />
0.5<br />
Alfa=0.6<br />
0.4<br />
0 20 40<br />
Rel. Downwind Distance<br />
MG 186 12<br />
Free wind speed:<br />
12 m/s ± 0.5 m/s<br />
(7 sets of data)<br />
Figure 6. <strong>Wind</strong> direction 186°±1°. Relative distance in rotor-diameters.<br />
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EWEC 2006 <strong>Wind</strong> Energy Conference and Exhibition<br />
1.100<br />
1.000<br />
Alfa=0.7<br />
Meas<br />
Free wind speed:<br />
Relative wind speed<br />
0.900<br />
0.800<br />
0.700<br />
0.600<br />
6 m/s ± 0.5 m/s<br />
0.500<br />
1.1<br />
155 165 175 185 195 205 215<br />
Relative <strong>Wind</strong> Speed<br />
1<br />
0.9<br />
0.8<br />
0.7<br />
0.6<br />
Alfa=0.7<br />
Meas<br />
Free wind speed:<br />
9 m/s ± 0.5 m/s<br />
Relative <strong>Wind</strong> Speed<br />
0.5<br />
155 165 175 185 195 205 215<br />
1.100<br />
1.000<br />
0.900<br />
0.800<br />
0.700<br />
0.600<br />
Alfa=0.7<br />
Meas<br />
Alfa=0.6<br />
Alfa=0.5<br />
Free wind speed:<br />
12 m/s ± 0.5 m/s<br />
0.500<br />
155 165 175 185 195 205 215<br />
<strong>Wind</strong> Direction<br />
MG Dir 12<br />
Figure 7. <strong>Wake</strong> dependence on southern wind direction of second turbine from South (WT19).<br />
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EWEC 2006 <strong>Wind</strong> Energy Conference and Exhibition<br />
4.2 Horns Rev <strong>Wind</strong> Farm data<br />
<strong>Model</strong> predictions were compared to measured wind data from the Horns Rev wind farm in the<br />
North Sea West of Esbjerg (see figure 8). Two wind directions were considered, both of which<br />
were selected to be along the lines of the wind farm to get the maximum wake effect: from due<br />
West (270°) and from about South-East (222°). The wind directions in relation to the wind farm<br />
layout is also shown in the figure. The actual wind direction was measured at a monitoring mast,<br />
while the wind speed was deduced from the turbine power production.<br />
6152<br />
WT01<br />
WT11<br />
WT21<br />
WT31<br />
WT41<br />
WT51<br />
WT61<br />
WT71<br />
WT81<br />
WT91<br />
6151<br />
WT02<br />
WT12<br />
WT22<br />
WT32<br />
WT42<br />
WT52<br />
WT62<br />
WT72<br />
WT82<br />
WT92<br />
WT03<br />
WT13<br />
WT23<br />
WT33<br />
WT43<br />
WT53<br />
WT63<br />
WT73<br />
WT83<br />
WT93<br />
Northing (km)<br />
6150<br />
270 deg.<br />
WT04<br />
WT05<br />
WT14<br />
WT15<br />
WT24<br />
WT25<br />
WT34<br />
WT35<br />
WT44<br />
WT45<br />
WT54<br />
WT55<br />
WT64<br />
WT65<br />
WT74<br />
WT75<br />
WT84<br />
WT85<br />
WT94<br />
WT95<br />
6149<br />
WT06<br />
WT16<br />
WT26<br />
WT36<br />
WT46<br />
WT56<br />
WT66<br />
WT76<br />
WT86<br />
WT96<br />
WT07<br />
WT17<br />
WT27<br />
WT37<br />
WT47<br />
WT57<br />
WT67<br />
WT77<br />
WT87<br />
WT97<br />
6148<br />
WT08<br />
WT18<br />
WT28<br />
WT38<br />
WT48<br />
WT58<br />
WT68<br />
WT78<br />
WT88<br />
WT98<br />
222 deg.<br />
6147<br />
423 424 425 426 427 428 429 430<br />
Easting (km)<br />
Figure 8 The “Horns Rev <strong>Wind</strong> Farm” layout.<br />
The wind farm consists of 80 V80 Vestas 2MW-turbines with a rotor diameter of 80m and a hub<br />
height of 70m. The spacing is about 7 rotor diameters.<br />
The arrows indicate the two wind directions investigated as well as the turbine lines, the data<br />
from which have been used in the comparison.<br />
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EWEC 2006 <strong>Wind</strong> Energy Conference and Exhibition<br />
Relative Speed<br />
1.1<br />
1<br />
0.9<br />
0.8<br />
0.7<br />
0.6<br />
0.5<br />
0.4<br />
Alfa=0.7<br />
Meas.<br />
Alfa=1.0<br />
0 10 20 30 40 50 60<br />
Free wind speed:<br />
9 m/s ± 0.5 m/s<br />
(9 sets of data)<br />
1.1<br />
1<br />
Free wind speed:<br />
Relative wind speed<br />
0.9<br />
0.8<br />
0.7<br />
0.6<br />
0.5<br />
0.4<br />
Alfa=0.7<br />
Meas.<br />
Alfa=0.5<br />
0 10 20 30 40 50 60<br />
12 m/s ± 0.5 m/s<br />
(5 sets of data)<br />
Rel. Downwind Distance<br />
(HR 270 12)<br />
Figure 9. <strong>Wind</strong> direction 270°±1°. Relative distance in rotor-diameters along W-E turbine line #4.<br />
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EWEC 2006 <strong>Wind</strong> Energy Conference and Exhibition<br />
1.1<br />
Free wind speed:<br />
1<br />
Relative Speed<br />
0.9<br />
0.8<br />
0.7<br />
0.6<br />
Alfa=0.7<br />
Meas.<br />
Alfa=0.5<br />
9 m/s ± 1 m/s<br />
(56 sets of data)<br />
0.5<br />
0.4<br />
0 20 40 60<br />
Rel. Downwind Distance<br />
Figure 10. <strong>Wind</strong> direction 222°±2°. Relative distance in rotor-diameters along diagonal line #7.<br />
5 DISCUSSION OF MODEL COMPARISON WITH DATA<br />
From the comparisons of the model prediction with the wind farm data the following points were<br />
observed:<br />
• The wind speed deficit at the first wake-effected turbine is generally predicted well;<br />
• The wake width is generally predicted well;<br />
• For positions with strong overlapping effects the speed deficit is mostly overpredicted, but<br />
underpredictions are also seen (the Horns Rev wind farm). Variations in the α-value indicate<br />
that improper modeling of the wake expansion is the cause.<br />
6 CONCLUSION<br />
The establishment of the semi-linear wake model, and the predictions made with it in comparison<br />
with accessible data from wind farms have lead to the following conclusions regarding the further<br />
development of the model:<br />
• The proposed semi-linear wake model is able to treat wind farms of irregular lay-out;<br />
• In the present version, the speed deficits are predicted qualitatively well, but the accuracy has<br />
yet to be improved;<br />
• The wake expansion coefficient <strong>for</strong> the wake from a certain turbine should be allowed to vary<br />
with the thrust coefficient and in response to the presence of other wake(s) overlapping with<br />
it. Further, at least <strong>for</strong> the wake originating from the first turbine in a line, it should be tested<br />
whether a wake expansion exponent of 1/k = 1/3 (also considered by Frandsen et al. [6])<br />
could give a better agreement with observation data.<br />
• The “mosaic-tile” wake model should be further investigated, and if possible it should be<br />
implemented with the aim of getting improved wake speed deficit predictions.<br />
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EWEC 2006 <strong>Wind</strong> Energy Conference and Exhibition<br />
7 ACKNOWLEDMENTS<br />
This work has in part been financed by the Danish Public Service Obligation (PSO) funds (F&U<br />
4103). Data from Middelgrunden wind farm were kindly provided by Københavns Miljø- og<br />
Energikontor, while data from Horns Rev wind farm were provided by Elsam Engineering.<br />
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[4] I. Katic, J. Højstrup and N.O.Jensen, A Simple <strong>Model</strong> <strong>for</strong> Cluster Efficiency. Proceedings of<br />
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[7] R.J.Barthelmie, S.T.Frandsen, P.-E.Rethore, M.Mechali, S.C.Pryor, L.Jensen and<br />
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