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TRANSPARENT ASSUMPTIONS · AS AT 20 OCTOBER 2026

How your estimate is calculated.

The calculator provides non-binding guidance for technical and commercial operations management. The graduated fee structure and minimum calculation shown here form a non-binding pricing model. A price commitment arises only from an individually reviewed proposal.

1. Yield: existing data takes priority

Where possible, use actual electricity exported to the grid over complete operating years, or a net energy yield assessment. Without these data, annual yield in MWh = installed capacity in MW × assumed equivalent full-load hours. Full-load hours express the annual energy output as the number of hours at rated power. The 1,800, 2,500 and 3,200-hour options reflect comparison sites in the 2024 Fraunhofer ISE study. They are not site-specific wind or turbine forecasts.

The commissioning date, location and turbine type support a later technical review. These details alone cannot reliably establish the wind resource, hub height effects, curtailment, availability, wind farm wake effects or technical constraints. The PDF also shows sensitivity scenarios with 15% lower and 15% higher yield. This is not a statistical prediction interval.

2. Revenue: clearly defined

Known annual net revenue takes priority. Alternatively, net revenue in euros = annual yield in MWh × 10 × average remuneration rate in euro cents/kWh − known annual electricity marketing deductions. Here, net means excluding VAT and after agreed marketing deductions, including relevant support payments. It does not mean profit after financing and operating costs.

The average remuneration rate may come from a PPA, market sales, a feed-in tariff, EEG remuneration in Germany or another arrangement. For multiple prices, use the annual average weighted by electricity volume: 60% of output at 7 cents and 40% at 5 cents gives 6.2 euro cents/kWh. Include relevant support payments once in the rate and avoid double-counting deductions. All amounts are calculated in euros; convert other currencies before entering them. Country-specific support rules and exchange rates are not calculated automatically.

For German assets, the site-specific EEG applicable value may serve as a simplified assumption. It does not guarantee revenue. Support eligibility, price risks and contract terms require an individual review in every market.

3. Graduated fees without sudden price changes

Each rate applies only to its corresponding portion of annual net revenue. This keeps the fee continuous as revenue increases. The effective overall rate is shown separately.

Portion of annual net revenueRate on that portion
First €350,0003.50%
Next €350,0002.50%
Next €800,0001.75%
Above €1,500,0001.00%

4. Minimum calculation and the 3.5% limit

The proposed annual minimum is €6,000 per wind farm plus €1,500 per turbine. We compare it with the graduated fee and use the higher amount, provided that it does not exceed 3.5% of net revenue. Otherwise, the calculator displays “Individual calculation required” and does not quote an automatic price.

Example: four turbines producing 8,000 MWh at an assumed 7 euro cents/kWh generate €560,000 in annual net revenue. The graduated fee is €17,500 per year excluding VAT, equivalent to 3.125%. The minimum of €12,000 does not apply in this example. This minimum and fee structure are calculation proposals, not existing contractual terms.

5. Scope of services

The estimate covers technical and commercial operations management within a scope to be agreed together. Maintenance, repairs, spare parts, expert assessments, insurance, direct electricity marketing and other third-party services are excluded. Availability commitments, response times, contract duration and the billing basis are agreed individually.

Sources and technical background

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