54 MW producing 173,887 MWh/yr (net CF 36.8%). LCOE 54 €/MWh vs a 68 €/MWh price. Bankable-looking: equity IRR 20.3%, minimum DSCR 1.75.
Annual energy (P50, year 1)
173.9GWh
48,302 average EU homes
Net capacity factor
36.8%
gross 43.2% · 3,220 full-load h
LCOE
54€/MWh
at 6.5% WACC over 30 years
Project IRR (unlevered)
12.6%
NPV 55 M€
Equity IRR
20.3%
70% debt at 5.5% over 15 years
Min / avg DSCR
1.75 / 1.85
debt service 5.27 M€/yr
Total capex
€75,600,000
435 € per annual MWh
Year-1 revenue
€11,824,328
opex 2,615,774 €
Simple payback
8 yrs
Wind farm area
6.4km²
rotor Ø 138 m · direct footprint ≈ 22 ha
CO₂ avoided per year
69.6kt
Project cash flows
| Year | Energy (MWh) | Revenue (k€) | Opex (k€) | CFADS (k€) | Debt service (k€) | DSCR | Equity cash (k€) |
|---|---|---|---|---|---|---|---|
| 1 | 173,887 | 11,824 | 2,616 | 9,209 | 5,272 | 1.75 | 3,936 |
| 2 | 173,192 | 11,954 | 2,667 | 9,287 | 5,272 | 1.76 | 4,015 |
| 3 | 172,499 | 12,084 | 2,719 | 9,366 | 5,272 | 1.78 | 4,094 |
| 4 | 171,809 | 12,217 | 2,771 | 9,445 | 5,272 | 1.79 | 4,173 |
| 5 | 171,122 | 12,350 | 2,825 | 9,525 | 5,272 | 1.81 | 4,253 |
| 6 | 170,437 | 12,485 | 2,880 | 9,605 | 5,272 | 1.82 | 4,333 |
| 7 | 169,755 | 12,622 | 2,936 | 9,686 | 5,272 | 1.84 | 4,413 |
| 8 | 169,076 | 12,760 | 2,994 | 9,766 | 5,272 | 1.85 | 4,494 |
| 9 | 168,400 | 12,900 | 3,052 | 9,848 | 5,272 | 1.87 | 4,576 |
| 10 | 167,726 | 13,041 | 3,111 | 9,929 | 5,272 | 1.88 | 4,657 |
| 11 | 167,056 | 13,183 | 3,172 | 10,012 | 5,272 | 1.9 | 4,739 |
| 12 | 166,387 | 13,328 | 3,234 | 10,094 | 5,272 | 1.91 | 4,822 |
| 13 | 165,722 | 13,474 | 3,297 | 10,177 | 5,272 | 1.93 | 4,905 |
| 14 | 165,059 | 13,621 | 3,361 | 10,260 | 5,272 | 1.95 | 4,988 |
| 15 | 164,399 | 13,770 | 3,426 | 10,344 | 5,272 | 1.96 | 5,071 |
| 16 | 163,741 | 13,921 | 3,493 | 10,427 | — | — | 10,427 |
| 17 | 163,086 | 14,073 | 3,561 | 10,512 | — | — | 10,512 |
| 18 | 162,434 | 14,227 | 3,631 | 10,596 | — | — | 10,596 |
| 19 | 161,784 | 14,382 | 3,701 | 10,681 | — | — | 10,681 |
| 20 | 161,137 | 14,540 | 3,774 | 10,766 | — | — | 10,766 |
| 21 | 160,492 | 14,699 | 3,847 | 10,852 | — | — | 10,852 |
| 22 | 159,850 | 14,860 | 3,922 | 10,938 | — | — | 10,938 |
| 23 | 159,211 | 15,022 | 3,999 | 11,024 | — | — | 11,024 |
| 24 | 158,574 | 15,187 | 4,077 | 11,110 | — | — | 11,110 |
| 25 | 157,940 | 15,353 | 4,156 | 11,197 | — | — | 11,197 |
| 26 | 157,308 | 15,521 | 4,237 | 11,284 | — | — | 11,284 |
| 27 | 156,679 | 15,690 | 4,320 | 11,371 | — | — | 11,371 |
| 28 | 156,052 | 15,862 | 4,404 | 11,458 | — | — | 11,458 |
| 29 | 155,428 | 16,036 | 4,490 | 11,546 | — | — | 11,546 |
| 30 | 154,806 | 16,211 | 6,737 | 9,474 | — | — | 9,474 |
- Energy from a generic 4.5 MW power curve (rotor Ø 138 m, air density 1.188 kg/m³) under a Weibull distribution, minus 15% total losses. Use the turbine supplier’s curve and a wake model (e.g. PyWake, WAsP) for a bankable P50.
- Pre-tax model: corporate tax, depreciation, grid fees, balancing costs and curtailment are not included. Lenders size debt on P90 (typically 8–12% below P50), so test a lower capacity factor.
- Land: the array area spans the whole layout; only about 1–3% of it is physically occupied (pads, roads, substation), and farming continues around the turbines.