Turbine Definition & Gross AEP
Hub-height wind conversion, turbine power curve and multi-year gross AEP
Installed
Reference Gross AEP: calculated from the calibrated hub-height hourly wind series and the selected turbine power curve. Wake effects, terrain-flow speed-up/turning, electrical losses, availability and curtailment are not included at this stage.
HybridAEP follows this job back to the complete calibrated multi-year series; it does not use only the representative year for annual AEP statistics.
Turbine definition / library
The Nordex N163 preset was digitized from document 2001493EN / F008_276_A12_EN Rev.12 (2024-10-09), Mode 0, using the fixed-density ρ=1.225 kg/m³ power and Ct columns. Upload/paste fields below override the built-in curves if you need to correct them or use project-specific OEM data.
15 is the current Zhytomyr/Vysoke benchmark; edit for another layout.
Hub-height wind conversion / vertical shear
ERA5 100 m is a reanalysis/model wind series, not a measurement mast. We use it as the chronological reference-level series. A site-specific vertical profile should come preferably from simultaneous mast/LiDAR measurements or a trustworthy multi-height wind resource source.
Two-point profile option — optional
Used only when Method = Local two-point α. Otherwise these fields are ignored. α = ln(V₂/V₁) / ln(z₂/z₁). For HH≈125 m, prefer profile levels close to/bracketing hub height, e.g. 100/150 m, rather than 10/100 m. Use V₁ and V₂ from the same source and the same averaging period (for example the same mast/LiDAR campaign or the same multi-height atlas period).
Source chain: Long-term Job #8 → Calibration Job #7 → ERA5 Job #6. The shear calculation must go back to ERA5 Job #6 because that job contains both V10 = 3.454 m/s and V100 = 5.861 m/s. Therefore α10–100 = 0.230. Job #8 is the later long-term analysis result; it does not create a new 10 m wind series. This remains a bulk ERA5 shear estimate, not a local measured α around 125 m.
Priority for HH≈125 m: simultaneous mast/LiDAR or trustworthy profile points near the hub height (ideally 100/150 m) → Local two-point α. If those data are unavailable, use the automatic ERA5 bulk α10–100. Manual α=0.14 is retained only for sensitivity checks.
Power curve — built-in preset or user override
Leave empty to use the selected built-in preset. If uploaded, the first two numeric columns are interpreted as wind speed [m/s] and turbine power [kW]. Project-specific OEM data are preferred when available.
If this field contains numeric rows, it overrides both the uploaded file and the built-in preset. Include the cut-out/zero-power endpoint explicitly when using a custom curve.
Ct curve — optional now, needed later for wake modelling
Leave empty to use the built-in Ct curve when a preset is selected. A pasted Ct table overrides an uploaded file and the preset. Ct does not change gross AEP here; it is stored for PyWake/FLORIS.
All complete years are always calculated first. Auto AEP cannot know the year until this turbine/power-curve calculation is finished; HybridAEP then chooses the real year whose 8760-normalized gross AEP is closest to the median gross AEP. Auto Wind reuses the previous Long-term Wind Resource choice (currently 2020). Manual selection overrides both. This only selects the real 8760/8784-hour profile exported downstream; the AEP of all years is still calculated.
Result terminology: the 10th/50th/90th percentiles are calculated from 8760-normalized annual gross AEP. The 10th percentile can be shown as a resource-only P90-exceedance proxy, but it is not a bankable P90 because wake, losses and model/measurement uncertainty are not included yet.
Calculation status
Job #10 done
100%

Completed

Result
Turbine
Nordex N163/5.X Mode 0
Farm rated power
85.500 MW
Built-in curve source
2001493EN / F008_276_A12_EN Rev. 12 (2024-10-09)
Curve air density
1.225 kg/m³
Power curve
Built-in digitized preset: Nordex N163/5.X - Mode 0 - 5.7 MW - HH125 - rho 1.225 | 2001493EN / F008_276_A12_EN Rev. 12 (2024-10-09) | rho=1.225 kg/m3
Hub height
125.0 m
Turbines
15
Shear α used
0.2297
Shear source
ERA5 job #6 bulk mean profile 10–100 m (V10=3.454 m/s, V100=5.861 m/s)
Complete AEP years
20 (2006–2025)
Interannual gross AEP variability
7.46%
Mean gross AEP (8760 eq.)
237.354 GWh
Median gross AEP (8760 eq.)
239.283 GWh
10th percentile annual gross AEP
214.857 GWh
90th percentile annual gross AEP
255.655 GWh
Energy Representative Year
2020
Wind Representative Year
2020
Selected simulation year
2020
Selected year gross AEP
238.880 GWh
Year selection logic
Auto: historical year with 8760-normalized gross AEP closest to the median.
Reusable selected-year generation
Zhytomyr_Vysoke_WPP2__Turbine_AEP__job000010__gross_generation_2020.csv.gz
Gross AEP only: wake and other project losses are not included yet. The 10th percentile is a resource-only P90-exceedance proxy, not a bankable P90.
Download Excel — Zhytomyr_Vysoke_WPP2__Turbine_AEP__job000010.xlsx Download CSV.gz
Excel export

Every completed calculation exports an XLSX workbook whose first worksheet is Cover. The Cover is written in English and documents purpose, inputs, method, outputs, limitations and source/documentation links.

Calculation logic / How this works

Define the turbine and independently calculate a transparent gross-AEP baseline before wake modelling. This gives a check against the later PyWake/FLORIS result.

  1. Select a completed Long-term Wind Resource job; HybridAEP follows it back to the full calibrated multi-year hourly wind dataset.
  2. Define turbine identity, rated power, rotor diameter, hub height and turbine count.
  3. Convert calibrated 100 m wind speed to hub height with an explicit power-law shear model. Default: derive the available ERA5 bulk α from 10/100 m. Preferred when available: derive a local α from two profile points close to/bracketing hub height, e.g. 100/150 m for HH125.
  4. Interpolate the supplied wind-speed/power curve for every hourly hub-height wind speed; values outside the supplied curve range are set to zero.
  5. Calculate gross AEP and capacity factor for each complete historical year, plus 8760-normalized annual AEP statistics.
  6. Select the downstream simulation year automatically from median AEP, from the wind-resource representative year, or manually.
ERA5 bulk α10–100 is an automatic fallback, not a local measured shear coefficient. If 100/150 m or similar site-profile data become available, Local two-point α should replace it for HH125. Manual α=0.14 remains only a sensitivity assumption. Gross AEP here is an independent baseline; PyWake/FLORIS later add wake effects.