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1. Wind Speed Extrapolation: If wind speed is provided at a reference height different from the turbine hub height, it is extrapolated using the Power Law for Wind Profile Scaling.
   As a rule:

   • If hub height < 100 m: use 10 m as reference

   • If hub height > 100 m: use 100 m as reference

   • If hub height = reference: no extrapolation is applied

   Figure 2.1 shows the difference in wind speeds between 150 m and 100 m as extrapolated using the power law, highlighting the relevance of height correction for tall turbines.

2. Power Curve Application: For each turbine and time step, the extrapolated wind speed is mapped onto a power output using the turbine's power curve (Figure 2.2).

3. Capacity Factor Calculation: The power output is converted to capacity factor (CF) by normalising the generated power

   Mathinline
   P_{gen}

   ​ by the rated (installed) capacity

   Mathinline
   P_{rated}

   ​ of the turbine:

CF = \frac{P_{gen}}{P_{rated}}

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Table 2.1: Selected turbine types used in the Wind Power model, showing their main technical parameters and the corresponding input wind-speed sources. The corresponding power curves are plotted in Figure 2.2. For turbines with hub heights ≥ 100 m, two capacity-factor versions are provided, based on the two WS100 products available in the historical dataset. 

*Note: in the historical stream and for turbines with hub heights ≥ 100 m (turbines # 0, 1, 3, 4), two versions of the wind power capacity factor are provided. 
These correspond to the two available WS100 products:

1. WS100 estimated from bias-adjusted WS10 using the power-law/Alpha formulation;

2. WS100 computed from ERA5 and bias-adjusted with GWA2.

Output Data

• Hourly gridded (NetCDF) wind power capacity factors per turbine type
• For the onshore wind power indicator (WON), after applying the Spatial Aggregation Procedure and the Temporal Aggregation Procedure, aggregated datasets are computed at the ADM0 and ADM1 levels for hourly, daily, monthly, seasonal, and annual temporal resolutions.

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