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Fixed-bottom offshore wind farm (monopile, 10-15 MW turbines): net yield after wake and availability, CAPEX build-up and LCOE

Fixed-bottom offshore wind farm on monopiles with 8-20 MW turbines: net yield after wake, outage and grid losses, installed CAPEX built up from the Danish Energy Agency 2025 depth and distance functions, O&M and LCOE in real 2023 EUR/MWh.

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Open Jack

Founder · OpenJack

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  • CurrencyEUR 2023
  • Battery limitinstalled
  • 73 documented assumptions
  • Updated2 Nov 2026

Mass and energy balance

What the asset draws and delivers for the case and load you choose.

Reference case

Capacity factor of the turbines before wake, availability and electrical losses, from a wind resource study of the site. Default 57.6 %: the value that returns the DEA 4,400 net full-load hours for the North Sea reference site (10.3 m/s at 100 m) under the North Sea case losses. It is a calibration on that single DEA figure, not a measurement.

Flows

    Asset

    Fixed-bottom offshore wind farm (monopile)

    • Out: Electricity (net, at the point of connection)—

    Annual quantities at the current usage.

    Size of the farm in turbines, the way DEA states it. Default 70, the DEA offshore datasheet farm. The slider stays inside the 15-75 turbine domain of the DEA sheets, where the source holds the cost per MW constant (no economies of scale modelled). 20-75 turbines of 8-20 MW give 160-1,500 MW.

    Farm capacity
    — MW
    Average net power
    — MW
    Net annual energy (GWh)
    — GWh/year
    Total CAPEX (MEUR)
    — MEUR

    CAPEX

    Specific cost at this size, what backs it, and how it behaves with scale.

    Specific CAPEX at this size

    —

    Reference size 70 turbines

    Danish Energy Agency Technology Data, ch. 21

    Model value: the DEA build-up (development, turbine, foundation, array cables, substation, export cable). Customized: your own all-in installed CAPEX per kW (for example a supplier or EPC quote), used as entered at every farm size. A customized value is no longer sourced.

    Specific CAPEX after the farm-size law by number of turbines

    Log in to view this sensitivity chart.

    1. Ex-factory
    2. Installed· this figure
    3. Fully financed
    CAPEX at the battery limit—
    Working capital, contingencyproject level

    Included

    • Equipment
    • Installation, civil works and engineering

    Not included

    • Working capital
    • Contingency

    Added at project level

    • Working capital layer, from the project settings
    • Contingency, from the project settings

    Project figures

    Values passed to project mode when this asset is added to a project.

    Concept sketch, not to scale · drag to rotate

    Electricity (net, at the point of connection) outMain product
    —
    CAPEX to the battery limit
    —
    Fixed O&M
    —
    Variable O&M, excluding feedstocks
    —
    Asset lifetime
    30 years

    Log in to add this asset to a project.

    Levelised cost of electricity

    A standalone indicator for a quick read. Project mode recomputes it for the whole system.

    —

    • LCOE, capital—
    • LCOE, fixed O&M—
    • LCOE, variable O&M—

    Linked to the balance above

    Capacity factor of the turbines before wake, availability and electrical losses, from a wind resource study of the site. Default 57.6 %: the value that returns the DEA 4,400 net full-load hours for the North Sea reference site (10.3 m/s at 100 m) under the North Sea case losses. It is a calibration on that single DEA figure, not a measurement.

    Nameplate power of one turbine, in MW as the catalog wind_turbine sheet stores it (the Siemens Gamesa SG 14-236 DD at 14 MW or the Vestas V236-15.0 MW at 15 MW prefill it). Default 15 MW, the DEA 2025 reference turbine (236 m rotor, 343 W/m2). The DEA costs are per MW, so the rating sets the farm capacity and not the cost per kW.

    Mean water depth at the monopile positions. It drives the foundation cost (DEA: 0.45 MEUR/MW + 5 kEUR/MW per m). 10-50 m is the envelope of the DEA bottom-fixed categories (Table 3); deeper sites need jackets or floating foundations.

    Length of the export route to the onshore connection point. It drives the AC export cable cost (DEA: 5.05 kEUR/MW/km). 10-100 km is the DEA AC range; beyond about 80 km compare with the HVDC calculator of the same batch by chaining it and setting the grid connection scope to 'chained'.

    Keep the AC offshore substation and AC export cable here for a stand-alone farm. When the farm is chained to the HVDC export calculator, choose 'chained': both AC lines are removed so the grid connection is not counted twice.

    Real weighted average cost of capital for the stand-alone LCOE, as a fraction. All costs are constant 2023 EUR, so the rate is real. Default 7 %, a financier-facing project rate; DEA computes its reference LCOE at 3.5 %, shown separately as 'LCOE at the DEA reference WACC'.

    Years over which the CAPEX is annualised. DEA assumes a 30-year technical lifetime for all offshore categories (datasheet range 25-40).

    Levelised cost of electricity by gross capacity factor

    Log in to view this sensitivity chart.

    Benchmarks

    This model's figures against published references and reference cases.

    Specific CAPEX, EUR/kW

    2,200 Benchmark (unit conversion of a cited figure: 1 MEUR/MW = 1,000 EUR/kW)

    3,000 Benchmark (unit conversion of a cited figure: 1 MEUR/MW = 1,000 EUR/kW)

    3,600 Benchmark (unit conversion of a cited figure: 1 MEUR/MW = 1,000 EUR/kW)

    5,400 Benchmark (unit conversion of a cited figure: 1 MEUR/MW = 1,000 EUR/kW)

    Model CAPEX in 2020 EUR, EUR/kW

    2,780 Benchmark (unit conversion of a cited figure: 1 MEUR/MW = 1,000 EUR/kW)

    Net full-load hours, h/year

    4,000 Danish Energy Agency Technology Data, ch. 21

    4,400 Danish Energy Agency Technology Data, ch. 21

    4,500 Danish Energy Agency Technology Data, ch. 21

    Reference cases at this size and usage

    Log in to compare the reference cases.

    All results

    Every model output at the current settings, grouped, with the sensitivity charts.

    56 outputs · 5 groups · 16 also shown above, dimmed

    Farm

    6
    Farm capacity
    ComputingMW
    DEA reference farm capacity
    ComputingMW
    Farm size against the DEA reference
    Computingratio
    Turbine rating against the DEA reference
    Computingratio
    Compare with HVDC
    Computingflag
    AC grid connection costed here
    Computingflag

    Energy and losses

    17
    Net capacity factor
    Computing%
    Gross full-load hours
    Computingh/year
    Net full-load hours
    Computingh/year
    Wake loss
    Computing%
    Outage loss rebuilt from DEA components
    Computing%
    Net-to-gross energy factor
    Computingratio
    Total losses
    Computing%
    Gross annual energy
    ComputingMWh/year
    Net annual energy
    ComputingMWh/year
    Net annual energy (GWh)
    ComputingGWh/year
    Energy lost to wakes
    ComputingMWh/year
    Energy lost to outages
    ComputingMWh/year
    Energy lost in the electrical system
    ComputingMWh/year
    Total energy losses
    ComputingMWh/year
    Net specific yield
    ComputingMWh/MW/year
    Average net power
    ComputingMW
    Net energy per turbine
    ComputingGWh/year

    CAPEX build-up

    19
    Project development
    ComputingEUR/kW
    Turbines, installed
    ComputingEUR/kW
    Monopile foundations, installed
    ComputingEUR/kW
    Inter-array cables
    ComputingEUR/kW
    Offshore AC substation
    ComputingEUR/kW
    AC export cable
    ComputingEUR/kW
    Model CAPEX (DEA build-up)
    ComputingEUR/kW
    Lowest model CAPEX in the domain
    ComputingEUR/kW
    Specific CAPEX after the farm-size law
    ComputingEUR/kW
    Specific CAPEX
    ComputingEUR/kW
    Specific CAPEX, low end of the DEA uncertainty
    ComputingEUR/kW
    Specific CAPEX, high end of the DEA uncertainty
    ComputingEUR/kW
    Model CAPEX in 2020 EUR
    ComputingEUR/kW
    Total CAPEX
    ComputingEUR
    Total CAPEX (MEUR)
    ComputingMEUR
    CAPEX per turbine position
    ComputingMEUR
    Foundation share of model CAPEX
    Computing%
    Grid connection share of model CAPEX
    Computing%
    Indicative HVDC grid connection at DEA unit costs
    ComputingEUR/kW

    O&M

    4
    Fixed O&M
    ComputingEUR/year
    Variable O&M
    ComputingEUR/year
    Total O&M
    ComputingEUR/year
    O&M per kW
    ComputingEUR/kW/year

    Levelised cost and finance

    10
    Capital recovery factor
    Computing1/year
    Annualised CAPEX
    ComputingEUR/year
    Total annual cost
    ComputingEUR/year
    LCOE, capital
    ComputingEUR/MWh
    LCOE, fixed O&M
    ComputingEUR/MWh
    LCOE, variable O&M
    ComputingEUR/MWh
    Levelised cost of electricity
    ComputingEUR/MWh
    Capital share of the LCOE
    Computing%
    Capital recovery factor at the DEA 3.5 % WACC
    Computing1/year
    LCOE at the DEA reference WACC
    ComputingEUR/MWh

    Sensitivities

    5 charts
    LCOE and net capacity factor against the gross capacity factor

    Log in to view this sensitivity chart.

    LCOE components against the gross capacity factor

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    Specific CAPEX and foundation line against water depth

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    Grid connection cost and LCOE against distance to shore

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    LCOE against the real WACC

    Log in to view this sensitivity chart.

    Sources

    About

    Calculator context

    A screening model of a fixed-bottom offshore wind farm on monopiles, built on the Danish Energy Agency (DEA) Technology Data for offshore wind (chapter 21, updated February 2025) so that every cost line can be traced to a printed figure. It returns the farm capacity, the net annual energy and net capacity factor, the installed CAPEX broken down line by line, the O&M and a levelised cost of electricity in real 2023 EUR.

    Inputs. The turbine rating in MW (the unit of the catalog wind_turbine sheet: the Siemens Gamesa SG 14-236 DD at 14 MW or the Vestas V236-15.0 MW at 15 MW prefill it), the number of turbines, the water depth, the distance to shore, the gross capacity factor of the site, the grid connection scope, a reference case, an optional customized CAPEX, and the real WACC and lifetime of the stand-alone LCOE.

    Energy. Net energy = farm capacity x 8,760 h x gross capacity factor x (1 - wake loss) x (1 - 3 % outages) x (1 - 2 % grid losses). The outage and grid losses are the DEA datasheet values (note B). The wake loss is set by the case: 8.3 %, the United Kingdom country value of Warder & Piggott 2025 (the closest published North Sea figure), or 13 %, their value for the United States, Australia and China. The default gross capacity factor, 57.6 %, is the value that returns the DEA 4,400 net full-load hours for the North Sea reference site (10.3 m/s at 100 m, 15 MW turbines with a 236 m rotor) under the North Sea losses: a one-point calibration, so the nominal net capacity factor of 50.2 % equals the DEA figure by construction and validates nothing. Enter the gross capacity factor of your site from a wind resource study.

    CAPEX. The DEA Table 7 functions, installation included: development 0.20 MEUR/MW, turbines 1.35 MEUR/MW, monopile foundations 0.45 MEUR/MW + 5 kEUR/MW per metre of depth, array cables 0.05 MEUR/MW, AC offshore substation 0.65 MEUR/MW and AC export cable 5.05 kEUR/MW per km. At 30 m and 60 km the sum is 3,153 EUR2023/kW; deflated with the DEA index (1.133) it is 2.783 MEUR2020/MW against the 2.78 printed in the independent datasheet total. DEA also prints about 3.0 MEUR2023/MW for a Thor-like site, which the formula gives at about 25 km. The perimeter is the DEA one: equipment, installation and development, without site lease, contingency, financing and decommissioning. It is declared 'installed', so project mode adds only working capital and contingency. Over the admitted ranges (10-50 m, 10-100 km) the formula spans 2,800-3,455 EUR/kW, the lower half of the WindEurope 2023 European range of 2.2-5.4 MEUR/MW (capacity-weighted average 3.6), whose perimeter varies by country.

    Farm size. DEA states that economies of scale are not part of its calculations: the same per-MW unit costs serve its 20-turbine and 70-turbine sheets. The cost per kW is therefore constant in farm size and in turbine rating, as in the source, inside the 15-75 turbine domain of the DEA sheets (the slider covers 20-75 turbines, 160-1,500 MW). No sourced farm-size exponent was found, so none is applied; real economies of scale outside that domain are not modelled. A supplier or EPC quote can replace the model CAPEX through the 'Customized' option.

    Grid connection and HVDC. The AC export is valid to 100 km (DEA Table 3). Beyond about 80 km, compare with the HVDC export calculator of the same batch: chain it and set the grid connection scope to 'chained', which removes the AC substation and AC export cable from this calculator so they are not counted twice. An indicative HVDC figure at DEA DC unit costs (1.20 MEUR/MW substation + 3.60 kEUR/MW per km) is shown for orientation only.

    O&M and LCOE. DEA fixed O&M 50,000 EUR/MW per year and variable O&M 5 EUR/MWh. LCOE = (total CAPEX x capital recovery factor + O&M) / net energy, all in constant 2023 EUR with a real WACC. With the DEA reference case (70 x 15 MW, 30 m, 60 km, 30 years) the LCOE is about 55 EUR/MWh at the DEA 3.5 % WACC; the default rate is 7 %, a financier-facing project rate, which gives about 74 EUR/MWh. The LCOE at the DEA 3.5 % is always shown alongside. Interest during the 3.5-year construction is not included.

    Model

    131 variables — inputs, calculations and outputs, with their dependencies.

    131 variables shown of 131
    VariableValueUnitDepends on
    1——
    15MW—
    70turbines—
    30m—
    60km—
    1——
    57.6%—
    0——
    3600EUR/kW—
    0.07ratio—
    30years—
    VariableFormulaUnitDepends on
    if((<=)+(<)+(<)+(>)+(<)+(>)+(<=)+(*>)+(<)+(<=)+(<)+(>)+(<)+(>)+(<)+(>)+(<=)>0,1,0)bool
    *ratio
    VariableFormulaUnitDepends on
    *MW
    *MW
    /max(,)ratio
    /max(,)ratio
    if(==,,)%
    +*//%
    (-*)*(-*)*(-*)ratio
    (-)/%
    *%
    **h/year
    **h/year
    *MWh/year
    *MWh/year
    *GWh/year
    **MWh/year
    (-)**MWh/year
    (--)**MWh/year
    -MWh/year
    /max(,)MWh/MW/year
    /MW
    /max(,)GWh/year
    *EUR/kW
    *EUR/kW
    (+*)*EUR/kW
    *EUR/kW
    if(==,,)flag
    **EUR/kW
    ***EUR/kW
    +++++EUR/kW
    (+++*+)*EUR/kW
    if(>=,,clamp(*(/)^(-),,*))EUR/kW
    EUR/kW
    *(-*)EUR/kW
    *(+*)EUR/kW
    /EUR/kW
    **EUR
    *MEUR
    /max(,)MEUR
    /max(,)/%
    (+)/max(,)/%
    (+*)*EUR/kW
    if(>,,)flag
    *EUR/year
    *EUR/year
    +EUR/year
    /max(*,)EUR/kW/year
    if(<,/,(*(+)^)/max((+)^-,))1/year
    *EUR/year
    +EUR/year
    /max(,)EUR/MWh
    /max(,)EUR/MWh
    /max(,)EUR/MWh
    ++EUR/MWh
    /max(,)/%
    (*(+)^)/max((+)^-,)1/year
    (*+)/max(,)EUR/MWh

    Assumptions

    73 assumptions used in the calculations

    • Prevents division by zero.

      Market range Exact.

      0.000001
      Unit conversion / numerical constant

    • Lower bound used in the validity guard and switches.

      Market range Exact.

      0
      Unit conversion / numerical constant

    • Unit value used in the CRF, the loss factors and the switches.

      Market range Exact.

      1
      Unit conversion / numerical constant

    • Annualises capacity factors into energy.

      Market range Exact.

      8760h/year
      Unit conversion / numerical constant

    • Converts % inputs and constants to fractions.

      Market range Exact.

      0.01
      Unit conversion / numerical constant

    • Converts farm capacity to kW for the EUR/kW figures.

      Market range Exact.

      1000kW/MW
      Unit conversion / numerical constant

    • Converts the DEA cost lines (MEUR/MW) to EUR/kW.

      Market range Exact.

      1000(EUR/kW)/(MEUR/MW)
      Unit conversion / numerical constant

    • Reports totals in MEUR.

      Market range Exact.

      0.000001MEUR/EUR
      Unit conversion / numerical constant

    • Reports energy in GWh.

      Market range Exact.

      0.001GWh/MWh
      Unit conversion / numerical constant

    • Converts the DEA planned outage (weeks per year) to a share of the year.

      Market range Exact.

      7d/week
      Unit conversion / numerical constant

    • Converts the DEA planned outage (weeks per year) to a share of the year.

      Market range Exact.

      365d/year
      Unit conversion / numerical constant

    • Integer id of the DEA North Sea case (wake loss 8.3 %).

      Market range Not applicable (identifier).

      1
      Selector identifier

    • Integer id of the high-wake case (wake loss 13 %).

      Market range Not applicable (identifier).

      2
      Selector identifier

    • Validity guard on the case selector.

      Market range Not applicable (identifier).

      1
      Selector identifier

    • Validity guard on the case selector.

      Market range Not applicable (identifier).

      2
      Selector identifier

    • Integer id of the stand-alone AC grid connection scope.

      Market range Not applicable (identifier).

      1
      Selector identifier

    • Integer id of the chained scope (AC substation and AC export removed here).

      Market range Not applicable (identifier).

      2
      Selector identifier

    • Turbine rating of the DEA 2025 reference case; default of the rated power slider.

      Market range No independent range cited.

      15MW
      Danish Energy Agency Technology Data, ch. 21

    • Farm size of the DEA reference case; default of the turbine count.

      Market range No independent range cited.

      70turbines
      DEA datasheet 21 Offshore Wind AC Fixed

    • Reference size of the farm-size law (the cost anchor of the cited source).

      Market range No independent range cited.

      70turbines
      DEA datasheet 21 Offshore Wind AC Fixed

    • Water depth of the DEA reference case.

      Market range No independent range cited.

      30m
      Danish Energy Agency Technology Data, ch. 21

    • Distance to shore of the DEA reference case.

      Market range No independent range cited.

      60km
      Danish Energy Agency Technology Data, ch. 21

    • Lower validity bound of the depth-dependent foundation function.

      Market range Monopile practice roughly 10-50 m (DEA Table 3 envelope).

      10m
      Danish Energy Agency Technology Data, ch. 21

    • Upper validity bound of the depth-dependent foundation function.

      Market range Monopile practice roughly 10-50 m (DEA Table 3 envelope).

      50m
      Danish Energy Agency Technology Data, ch. 21

    • Lower validity bound of the AC export cable function.

      Market range No independent range cited.

      10km
      Danish Energy Agency Technology Data, ch. 21

    • Upper validity bound of the AC export cable function; beyond it, DEA switches to HVDC.

      Market range No independent range cited.

      100km
      Danish Energy Agency Technology Data, ch. 21

    • Calibration point of the default gross capacity factor and benchmark of the net full-load hours.

      Market range No independent range cited.

      4400h/year
      Danish Energy Agency Technology Data, ch. 21

    • Benchmark of the net full-load hours (nearshore site).

      Market range No independent range cited.

      4000h/year
      Danish Energy Agency Technology Data, ch. 21

    • Benchmark of the net full-load hours (far-shore site).

      Market range No independent range cited.

      4500h/year
      Danish Energy Agency Technology Data, ch. 21

    • Site description of the DEA reference case behind the 4,400 h; shown in the specifications.

      Market range No independent range cited.

      10.3m/s
      Danish Energy Agency Technology Data, ch. 21

    • Specific power of the DEA reference turbine; shown in the specifications.

      Market range No independent range cited.

      343W/m2
      Danish Energy Agency Technology Data, ch. 21

    • Rotor diameter of the DEA reference turbine; shown in the specifications.

      Market range No independent range cited.

      236m
      Danish Energy Agency Technology Data, ch. 21

    • Component of the DEA outage loss; used to show how the 3 % availability loss is built.

      Market range No independent range cited.

      2%
      DEA datasheet 21 Offshore Wind AC Fixed

    • Component of the DEA outage loss.

      Market range No independent range cited.

      0.5weeks/year
      DEA datasheet 21 Offshore Wind AC Fixed

    • Availability (outage) loss applied to the energy after wakes.

      Market range No independent range cited.

      3%
      DEA datasheet 21 Offshore Wind AC Fixed

    • Electrical (array, substation, export) loss applied after outages.

      Market range No independent range cited.

      2%
      DEA datasheet 21 Offshore Wind AC Fixed

    • Wake loss of the North Sea case (country value for the United Kingdom, the closest published North Sea figure).

      Market range Country averages 8.3 % (UK) to about 13 % (US, Australia, China) and 19.3 % (Brazil) in the same study.

      8.3%
      Warder & Piggott 2025

    • Wake loss of the high-wake case.

      Market range 8.3 % (UK) to 19.3 % (Brazil) in the same study.

      13%
      Warder & Piggott 2025

    • Default of the gross capacity factor slider: the value that returns the DEA 4,400 net hours under the North Sea case losses.

      Market range No independent range cited.

      57.6%
      Derived from DEA Table 5 and the loss constants

    • Development cost line of the CAPEX build-up.

      Market range No independent range cited.

      0.2MEUR/MW
      Danish Energy Agency Technology Data, ch. 21

    • Turbine line of the CAPEX build-up, installed.

      Market range No independent range cited.

      1.35MEUR/MW
      Danish Energy Agency Technology Data, ch. 21

    • Depth-independent part of the monopile foundation line, installed.

      Market range No independent range cited.

      0.45MEUR/MW
      Danish Energy Agency Technology Data, ch. 21

    • Depth-dependent part of the foundation line.

      Market range No independent range cited.

      0.005MEUR/MW/m
      Danish Energy Agency Technology Data, ch. 21

    • Inter-array cable line, installed.

      Market range No independent range cited.

      0.05MEUR/MW
      Danish Energy Agency Technology Data, ch. 21

    • Offshore AC substation line, installed.

      Market range No independent range cited.

      0.65MEUR/MW
      Danish Energy Agency Technology Data, ch. 21

    • AC export cable line, per km of distance to shore.

      Market range No independent range cited.

      0.00505MEUR/MW/km
      Danish Energy Agency Technology Data, ch. 21

    • DC export cable unit cost, used only for the indicative HVDC comparison output.

      Market range No independent range cited.

      0.0036MEUR/MW/km
      Danish Energy Agency Technology Data, ch. 21

    • DC converter substation unit cost, used only for the indicative HVDC comparison output.

      Market range No independent range cited.

      1.2MEUR/MW
      Danish Energy Agency Technology Data, ch. 21

    • Datasheet total that the Table 7 formula must reproduce at 30 m and 60 km once deflated to 2020 EUR.

      Market range No independent range cited.

      2.78MEUR/MW
      DEA datasheet 21 Offshore Wind AC Fixed

    • Deflates the 2023 EUR model CAPEX to 2020 EUR for the datasheet comparison.

      Market range No independent range cited.

      1.133
      Danish Energy Agency Technology Data, ch. 21

    • Independent DEA point estimate used as a benchmark.

      Market range No independent range cited.

      3MEUR/MW
      Danish Energy Agency Technology Data, ch. 21

    • Low end of the published European range (benchmark).

      Market range No independent range cited.

      2.2MEUR/MW
      WindEurope via DEA ch.21

    • High end of the published European range; ceiling of the CAPEX guard (never reached by the DEA formula inside its domain).

      Market range No independent range cited.

      5.4MEUR/MW
      WindEurope via DEA ch.21

    • Benchmark of the specific CAPEX.

      Market range No independent range cited.

      3.6MEUR/MW
      WindEurope via DEA ch.21

    • Width of the CAPEX uncertainty band shown next to the specific CAPEX.

      Market range No independent range cited.

      10%
      DEA datasheet 21 Offshore Wind AC Fixed

    • Farm-size law of the source: the DEA cost model scales linearly with capacity (per-MW unit costs, identical for 20- and 70-turbine farms), so the source states no economies of scale inside its 15-75 turbine domain. Outside that domain economies of scale are not modelled, and no sourced farm-size exponent was found to replace it.

      Market range No sourced farm-size exponent found for bottom-fixed farms.

      1
      Danish Energy Agency Technology Data, ch. 21

    • Fixed O&M per MW of farm capacity.

      Market range No independent range cited.

      50000EUR/MW/year
      Danish Energy Agency Technology Data, ch. 21

    • Variable O&M per MWh of net output.

      Market range No independent range cited.

      5EUR/MWh
      Danish Energy Agency Technology Data, ch. 21

    • Physical service life exported to project mode; default of the lifetime input.

      30years
      Danish Energy Agency Technology Data, ch. 21

    • Real WACC of the DEA reference LCOE; used for the comparison output at the DEA rate.

      Market range No independent range cited.

      3.5%
      DEA Technology Brief Feb 2025

    • Shown in the specifications; interest during construction is not in the DEA CAPEX and is left to project mode.

      Market range No independent range cited.

      3.5years
      DEA datasheet 21 Offshore Wind AC Fixed

    • Flag threshold above which chaining the HVDC calculator is suggested for comparison.

      Market range No independent range cited.

      80km
      Model convention

    • Benchmark for the specific CAPEX.

      Market range No independent range cited.

      3600EUR/kW
      Benchmark (unit conversion of a cited figure: 1 MEUR/MW = 1,000 EUR/kW)

    • Benchmark: low end of the European 2023 range.

      Market range No independent range cited.

      2200EUR/kW
      Benchmark (unit conversion of a cited figure: 1 MEUR/MW = 1,000 EUR/kW)

    • Benchmark: high end of the European 2023 range.

      Market range No independent range cited.

      5400EUR/kW
      Benchmark (unit conversion of a cited figure: 1 MEUR/MW = 1,000 EUR/kW)

    • Benchmark: DEA point estimate for a Thor-like Danish North Sea site, same perimeter as the model.

      Market range No independent range cited.

      3000EUR/kW
      Benchmark (unit conversion of a cited figure: 1 MEUR/MW = 1,000 EUR/kW)

    • Benchmark for the model CAPEX in 2020 EUR: the datasheet total at 30 m and 60 km.

      Market range No independent range cited.

      2780EUR/kW
      Benchmark (unit conversion of a cited figure: 1 MEUR/MW = 1,000 EUR/kW)

    • CAPEX = development + turbine + foundation(depth) + array cables + AC substation + AC export cable(distance), per MW, in 2023 EUR.

      Market range No independent range cited.

      —
      Method

    • The CAPEX is installed (equipment + installation + development) and excludes site lease, contingency, financing and decommissioning: declared battery_limit 'installed', so project mode adds only its working-capital layer and contingency.

      Market range No independent range cited.

      —
      Method

    • Cost per MW held constant in farm size and turbine rating, as the source does, inside the 15-75 turbine domain of the DEA sheets. Economies of scale outside it are not modelled.

      Market range No independent range cited.

      —
      Method

    • Net energy = farm capacity x 8,760 x gross capacity factor x (1 - wake) x (1 - outage) x (1 - grid loss).

      Market range No independent range cited.

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      Method

    • LCOE = (total CAPEX x CRF + fixed O&M + variable O&M) / net annual energy, constant 2023 EUR and a real WACC. Interest during construction (3.5-year build), lease, contingency and decommissioning are outside this stand-alone figure.

      Market range No independent range cited.

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      Method

    • Above about 80 km, chain the HVDC export calculator of the same batch and set the grid connection scope to 'chained': the AC substation and AC export cable are then removed here.

      Market range No independent range cited.

      —
      Method