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DC fast-charging hub for electric vehicles

One to twelve DC fast chargers of 50-400 kW: energy delivered, subscribed grid power, conversion losses, installed CAPEX from ICCT 2019 and the levelised cost per kWh delivered (NREL LCOC), with an optional sale margin.

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Open Jack

Founder · OpenJack

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  • CurrencyEUR 2019
  • Battery limitinstalled
  • 76 documented assumptions
  • Updated2 Nov 2026

Mass and energy balance

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

Reference case

Energy delivered as a share of the maximum (all chargers at full power all year), NREL definition. NREL profiles: p2 urban 50 kW 11.72 %, p3 4 x 150 kW 13.67 %, p4 20 x 150 kW 20.70 %. 13.67 % at 150 kW = 492 kWh per charger per day.

Flows

  • In: Grid electricity—

Asset

DC fast-charging hub for electric vehicles

  • Out: EV charging service (energy delivered to vehicles)—

Annual quantities at the current usage.

DC output power of ONE charger, in kW. Alpitronic Hypercharger HYC50 = 50 kW; HYC200 = 100 to 200 kW. The ICCT cost points sit at 50, 150 and 350 kW; 350-400 kW is extrapolated.

Site rated power
— kW
Subscribed power
— kW
Maximum deliverable energy
— MWh/yr

CAPEX

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

Specific CAPEX at this size

—

Reference size 150 kW

Derived from ICCT 2019 Table 2

Model value: ICCT 2019 price, scaled with rated power. Customized: your supplier quote per kW, used as entered at every power; the price is then no longer sourced. Installation stays modelled.

Charger purchase price per kW by rated power per charger

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  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

Grid electricity in
—
EV charging service (energy delivered to vehicles) outMain product
—
CAPEX to the battery limit
—
Fixed O&M
—
Variable O&M, excluding feedstocks
0 EUR/year
Asset lifetime
15 years

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Cost per kWh delivered

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

—

  • Capital—
  • Maintenance and network fee—
  • Demand charge—
  • Electricity—

Linked to the balance above

Energy delivered as a share of the maximum (all chargers at full power all year), NREL definition. NREL profiles: p2 urban 50 kW 11.72 %, p3 4 x 150 kW 13.67 %, p4 20 x 150 kW 20.70 %. 13.67 % at 150 kW = 492 kWh per charger per day.

Chargers on the site. Sets the ICCT installation tranche (1, 2, 3-5, 6+ per site). NREL profile p3 = 4 x 150 kW. Above 2.5 MW of site power ICCT warns of a cost step.

Price of the grid electricity bought, excluding VAT. Eurostat EU average for non-household consumers, S1 2026: 180 EUR/MWh (it already includes an average share of network charges).

Yearly charge per kW of subscribed power. Stadtwerke Mosbach 2025, MV/LV transformer, up to 2,500 h/a: 18.61 EUR/kW/a. Set 0 if your energy price already covers it.

One-off contribution per kW of subscribed power (German BKZ). enercity Netz 2025, MV/LV: 38.46 EUR/kW; Stadtwerke Elbtal 2026, MV: 137.04 EUR/kW.

Optional price per kWh charged to drivers, excluding VAT. Leave 0 for no margin calculation.

Real rate: CAPEX and O&M are in constant 2019 money. NREL LCOC uses 3.5 %.

Service life of the chargers. NREL LCOC: 15 years; US DOE 2015: at least 10 years.

Cost per kWh delivered by utilisation

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Benchmarks

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

Cost per kWh delivered, EUR/kWh

0.1251 NREL LCOC 2020 converted at ECB 2019

0.1608 NREL LCOC 2020 converted at ECB 2019

0.2769 NREL LCOC 2020 converted at ECB 2019

Purchase price per charger, EUR

80,393 NREL LCOC 2020 converted at ECB 2019

Installation per charger, EUR

53,595 NREL LCOC 2020 converted at ECB 2019

Reference cases at this size and usage

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All results

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

49 outputs · 5 groups · 14 also shown above, dimmed

Cost of charging

8
Cost per kWh delivered
ComputingEUR/kWh
Cost per MWh delivered
ComputingEUR/MWh
Capital
ComputingEUR/kWh
Maintenance and network fee
ComputingEUR/kWh
Demand charge
ComputingEUR/kWh
Electricity
ComputingEUR/kWh
Capital share of the cost
Computing%
Electricity share of the cost
Computing%

Energy and grid

12
Energy delivered
ComputingMWh/yr
Energy per charger per day
ComputingkWh/d
Full-load hours
Computingh/year
Maximum deliverable energy
ComputingMWh/yr
Site rated power
ComputingkW
Subscribed power
ComputingkW
Average grid draw
ComputingkW
Conversion efficiency
Computing%
Grid energy per kWh delivered
ComputingkWh/kWh
Grid electricity drawn
ComputingMWh/yr
Conversion losses
ComputingMWh/yr
Above the 2.5 MW cost step
Computingbool

CAPEX

10
Installed CAPEX
ComputingEUR
Chargers and installation
ComputingEUR
Grid connection fee
ComputingEUR
CAPEX per kW of site power
ComputingEUR/kW
Charger purchase price per kW
ComputingEUR/kW
Model purchase price per kW
ComputingEUR/kW
Purchase price per charger
ComputingEUR
Installation per charger
ComputingEUR
Purchase price exponent applied
Computingratio
Installation exponent above 150 kW
Computingratio

Annual costs and margin

10
Capital recovery factor
Computing1/year
Annualised CAPEX
ComputingEUR/year
Maintenance
ComputingEUR/year
Network fee
ComputingEUR/year
Demand charge per year
ComputingEUR/year
Fixed O&M per year
ComputingEUR/year
Electricity bill per year
ComputingEUR/year
Total annual cost
ComputingEUR/year
Margin per kWh
ComputingEUR/kWh
Margin per year
ComputingEUR/year

References

9
Cost at NREL p2 utilisation
ComputingEUR/kWh
Cost at NREL p4 utilisation
ComputingEUR/kWh
Cost at NREL p1 utilisation
ComputingEUR/kWh
Electricity cost at -25 C
ComputingEUR/kWh
NREL LCOC, p3
ComputingEUR/kWh
NREL LCOC, p4
ComputingEUR/kWh
NREL LCOC, p2 high
ComputingEUR/kWh
NREL equipment, 150 kW
ComputingEUR
NREL installation, 150 kW
ComputingEUR

Sensitivities

4 charts
Cost per kWh by component vs utilisation

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Purchase price per kW and cost per kWh vs rated power

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Installed CAPEX vs number of chargers

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Energy delivered and drawn vs utilisation

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Sources

76 documented assumptions · 12 sources

About

Calculator context

A screening model of a DC fast-charging hub: one to twelve chargers of 50 to 400 kW each, fed from the grid, selling energy to electric vehicles. It answers what a lender or a site owner asks first: how much energy the hub delivers, how much grid power it must subscribe, what it costs to build, and what each kWh delivered costs.

Method. The levelised cost of charging follows NREL (Borlaug et al., Joule 2020): installed CAPEX annualised with the capital recovery factor, plus maintenance (1 % of the charger purchase price per year), a 600 USD/yr network fee and a demand charge on the subscribed power, plus grid electricity grossed up for conversion losses, all divided by the energy delivered. Utilisation is NREL's: delivered energy over chargers x power x 8,760 h; the default 13.67 % is NREL profile p3 (four 150 kW chargers).

CAPEX. The charger purchase price comes from ICCT 2019 Table 2 (28,401 / 75,000 / 140,000 USD at 50 / 150 / 350 kW), interpolated log-log: exponent 0.884 up to 150 kW and 0.737 above, both derived from the table, extended to 400 kW. Installation comes from ICCT Table 4, by power and by number of chargers per site (1, 2, 3-5, 6+), and covers labour, materials, permits and taxes, not signage, lighting or surveillance. The grid connection contribution is the subscribed power times a German BKZ tariff (enercity Netz 2025, 38.46 EUR/kW). Costs are 2019 USD converted at the ECB 2019 average, 1.1195 USD/EUR, without escalation; a supplier quote can replace the purchase price.

Efficiency. Three sourced references: 93 % measured by the JRC at ambient temperature on chargers up to 50 kW, and the 97 % and 97.5 % peaks of the Alpitronic HYC50 and HYC200 datasheets. The JRC measured as low as 39 % at -25 C; the cold-weather output shows the electricity cost per kWh at that value.

Limits. Above 2.5 MW of site power ICCT expects a step change in cost (substation); the model flags it and does not price it. The Eurostat non-household price already includes an average share of network costs, so the separate demand charge double-counts part of it, conservatively. NREL's published LCOC for the same configuration (0.18 USD/kWh, 2019) uses US electricity prices and ICCT/NREL-family costs: it is a placement, not an independent check. Below 5 % utilisation the result is a stranded asset, not a design case, and the model refuses it; NREL's remote profile at 1.14 % reaches 1.66-2.19 USD/kWh.

Model

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

127 variables shown of 127
VariableValueUnitDepends on
150kW—
4-—
13.67%—
1——
180EUR/MWh—
18.61EUR/kW/year—
38.46EUR/kW—
0EUR/kWh—
0——
450EUR/kW—
3.5%—
15years—
VariableFormulaUnitDepends on
if((<)+(>)+(<)+(>)+(<)+(>)+(<)+(>)+(<)+(<)+(<)+(<)+(<=)+(<)+(<)+(>)>,,)bool
kW
//EUR/kW
if(<=,,if(<=,,if(<=,,)))USD
if(<=,,if(<=,,if(<=,,)))USD
if(<=,,if(<=,,if(<=,,)))USD
ln(/)/ln(/)ratio
*ratio
+EUR/year
*kWh/yr
VariableFormulaUnitDepends on
if(==,,if(==,,))%
*kW
if(>,,)bool
**h/year
*/MWh/yr
*/kWh/d
*/MWh/yr
/(*)kWh/kWh
*MWh/yr
-MWh/yr
*kW
*/kW
if(<=,,)ratio
clamp(*(/)^(-),,)EUR/kW
if(>=,,)EUR/kW
*EUR
ln(/)/ln(/)ratio
if(<=,*(/)^,*(/)^)/EUR
*(+)EUR
*EUR
+EUR
/max(,)EUR/kW
if(<,/,(*(+)^)/max((+)^-,))1/year
*EUR/year
***EUR/year
/EUR/year
*EUR/year
++EUR/year
*EUR/year
+EUR/year
/max(,)EUR/kWh
(+)/max(,)EUR/kWh
/max(,)EUR/kWh
/max(,)EUR/kWh
/max(,)EUR/kWh
*EUR/MWh
/max(,)/%
/max(,)/%
if(>,-,)EUR/kWh
*EUR/year
//(*)EUR/kWh
/max(***,)+EUR/kWh
/max(***,)+EUR/kWh
/max(***,)+EUR/kWh
/EUR
/EUR
/EUR/kWh
/EUR/kWh
/EUR/kWh

Assumptions

76 assumptions used in the calculations

  • Zero, for guards, flags and the no-sale case.

    Market range Exact.

    0
    Convention

  • One, for flags, selector tests, the single-charger tranche and the CRF.

    Market range Exact.

    1
    Convention

  • Guards divisions against zero.

    Market range Exact.

    0.000001
    Convention

  • Converts a percentage into a fraction.

    Market range Exact.

    0.01
    Convention

  • Hours in a non-leap year; NREL defines utilisation against N x P x 8760.

    Market range Exact.

    8760h/year
    Convention

  • Days in a non-leap year, for the per-day energy per charger.

    Market range Exact.

    365d/year
    Convention

  • kWh in one MWh.

    Market range Exact.

    1000kWh/MWh
    Convention

  • Upper edge of the ICCT '2 chargers per site' installation tranche.

    Market range Exact.

    2-
    Convention

  • Upper edge of the ICCT '3-5 chargers per site' installation tranche; 6 and more fall in the last tranche.

    Market range Exact.

    5-
    Convention

  • Lower edge of the power domain: below 50 kW the ICCT cost points no longer apply (that is AC or low-power DC territory).

    Market range 50 kW is the lowest DC fast tier in ICCT 2019.

    50kW
    ICCT 2019 Table 2

  • Upper edge of the power domain. 350-400 kW is a short extrapolation of the ICCT 150-350 kW segment.

    Market range ICCT stops at 350 kW; 350-400 kW is extrapolated.

    400kW
    ICCT 2019 Table 2 (extrapolated)

  • Largest hub the model accepts. Above 2.5 MW of site power ICCT warns of a step change in cost, which the model flags but does not price.

    Market range No independent range cited for hub size.

    12-
    Model domain

  • Lower edge of the utilisation domain. Below 5 % the result is not a design case but a stranded-asset case; the p1 reference cost is shown as an output instead.

    Market range NREL DCFC profiles span 1.14-20.7 %.

    5%
    NREL LCOC 2020 profiles

  • Upper edge of the utilisation domain, about 1.5 x the busiest NREL profile.

    Market range Highest NREL profile: 20.7 %.

    30%
    NREL LCOC 2020 p4 (+ headroom)

  • Rejects discount rates above 12 % real, outside what a charging-hub financing would carry.

    Market range No independent range cited for the guard itself.

    12%
    Model domain

  • Integer id of the JRC measured-efficiency case.

    Market range Exact.

    1-
    Convention

  • Integer id of the HYC50 datasheet case.

    Market range Exact.

    2-
    Convention

  • Integer id of the HYC200 datasheet case.

    Market range Exact.

    3-
    Convention

  • Grid-to-vehicle efficiency of the default case. It is a measured value, but on chargers of 50 kW or less and at the best ambient condition: one anchor, so medium evidence.

    Market range 39 % at -25 C to 93 % at ambient (JRC 2018); 97-97.5 % datasheet peaks (Alpitronic).

    93%
    JRC 2018

  • Used only for the cold-weather reference output (electricity cost per kWh delivered at the -25 C efficiency). Not an annual average.

    Market range Lowest value measured by the JRC; a winter extreme.

    39%
    JRC 2018

  • Efficiency of the HYC50 case. A datasheet peak, not an annual average: it is the optimistic bound.

    Market range Datasheet peak; field averages are lower (JRC 93 %).

    97%
    Alpitronic HYC50 datasheet

  • Efficiency of the HYC200 case. A datasheet peak, the most optimistic value in the model.

    Market range Datasheet peak 97.5 %.

    97.5%
    Alpitronic HYC200 datasheet

  • Purchase price of one 50 kW charger, hardware only, never an installed cost.

    Market range NREL LCOC median for DCFC-50: 38,000 USD equipment.

    28401USD
    ICCT 2019 Table 2

  • Purchase price of one 150 kW charger; the anchor of the scale law (reference size 150 kW).

    Market range NREL LCOC median for DCFC-150: 90,000 USD equipment.

    75000USD
    ICCT 2019 Table 2

  • Purchase price of one 350 kW charger; the upper anchor of the scale law.

    Market range Single ICCT point; no independent 350 kW price cited.

    140000USD
    ICCT 2019 Table 2

  • Hardware cost exponent between 50 and 150 kW: cost x (P/150)^0.884, so the cost per kW falls by P^-0.116. Derived from two published points, not fitted on a population.

    Market range Derived value; 0.737 on the next segment.

    0.884
    Derived from ICCT 2019 Table 2

  • Declared scale exponent of the charger: from 150 kW up, each doubling of rated power multiplies the hardware cost by 2^0.737 = 1.67, so the cost per kW falls by P^-0.263. Below 150 kW the segment exponent is 0.884 (milder economies of scale). Extended from 350 to 400 kW.

    Market range 0.884 (50-150 kW) to 0.737 (150-350 kW) from the same table.

    0.737
    Derived from ICCT 2019 Table 2

  • Lower interpolation point of the ICCT cost grid.

    Market range Grid point.

    50kW
    ICCT 2019

  • Reference size of the scale law (the 150 kW ICCT cost point).

    Market range Grid point; also NREL profiles p3-p4.

    150kW
    ICCT 2019

  • Upper interpolation point of the ICCT cost grid.

    Market range Grid point.

    350kW
    ICCT 2019

  • Floor of the clamp on the hardware cost per kW. Checked at the slider corners: it does not bind.

    Market range No independent range cited for the guard.

    100EUR/kW
    Model guard

  • Ceiling of the clamp on the hardware cost per kW. Checked at the slider corners: it does not bind.

    Market range Guard only; no market range attached.

    2000EUR/kW
    Model guard

  • Installation cost per charger at 50 kW with 1 charger per site. Excludes signage, ground marking, lighting and video surveillance. Interpolated log-log in power between the 50/150/350 kW columns.

    Market range ICCT tranche 50 kW: 17,692-45,506 USD across site sizes.

    45506USD
    ICCT 2019 Table 4

  • Installation cost per charger at 50 kW with 2 chargers per site. Excludes signage, ground marking, lighting and video surveillance. Interpolated log-log in power between the 50/150/350 kW columns.

    Market range ICCT tranche 50 kW: 17,692-45,506 USD across site sizes.

    36235USD
    ICCT 2019 Table 4

  • Installation cost per charger at 50 kW with 3 to 5 chargers per site. Excludes signage, ground marking, lighting and video surveillance. Interpolated log-log in power between the 50/150/350 kW columns.

    Market range ICCT tranche 50 kW: 17,692-45,506 USD across site sizes.

    26964USD
    ICCT 2019 Table 4

  • Installation cost per charger at 50 kW with 6 or more chargers per site. Excludes signage, ground marking, lighting and video surveillance. Interpolated log-log in power between the 50/150/350 kW columns.

    Market range ICCT tranche 50 kW: 17,692-45,506 USD across site sizes.

    17692USD
    ICCT 2019 Table 4

  • Installation cost per charger at 150 kW with 1 charger per site. Excludes signage, ground marking, lighting and video surveillance. Interpolated log-log in power between the 50/150/350 kW columns.

    Market range ICCT tranche 150 kW: 18,577-47,781 USD across site sizes.

    47781USD
    ICCT 2019 Table 4

  • Installation cost per charger at 150 kW with 2 chargers per site. Excludes signage, ground marking, lighting and video surveillance. Interpolated log-log in power between the 50/150/350 kW columns.

    Market range ICCT tranche 150 kW: 18,577-47,781 USD across site sizes.

    38047USD
    ICCT 2019 Table 4

  • Installation cost per charger at 150 kW with 3 to 5 chargers per site. Excludes signage, ground marking, lighting and video surveillance. Interpolated log-log in power between the 50/150/350 kW columns.

    Market range NREL LCOC median installation for DCFC-150: 60,000 USD (single figure, no site-size split).

    28312USD
    ICCT 2019 Table 4

  • Installation cost per charger at 150 kW with 6 or more chargers per site. Excludes signage, ground marking, lighting and video surveillance. Interpolated log-log in power between the 50/150/350 kW columns.

    Market range ICCT tranche 150 kW: 18,577-47,781 USD across site sizes.

    18577USD
    ICCT 2019 Table 4

  • Installation cost per charger at 350 kW with 1 charger per site. Excludes signage, ground marking, lighting and video surveillance. Interpolated log-log in power between the 50/150/350 kW columns.

    Market range ICCT tranche 350 kW: 25,654-65,984 USD across site sizes.

    65984USD
    ICCT 2019 Table 4

  • Installation cost per charger at 350 kW with 2 chargers per site. Excludes signage, ground marking, lighting and video surveillance. Interpolated log-log in power between the 50/150/350 kW columns.

    Market range ICCT tranche 350 kW: 25,654-65,984 USD across site sizes.

    52541USD
    ICCT 2019 Table 4

  • Installation cost per charger at 350 kW with 3 to 5 chargers per site. Excludes signage, ground marking, lighting and video surveillance. Interpolated log-log in power between the 50/150/350 kW columns.

    Market range ICCT tranche 350 kW: 25,654-65,984 USD across site sizes.

    39097USD
    ICCT 2019 Table 4

  • Installation cost per charger at 350 kW with 6 or more chargers per site. Excludes signage, ground marking, lighting and video surveillance. Interpolated log-log in power between the 50/150/350 kW columns.

    Market range ICCT tranche 350 kW: 25,654-65,984 USD across site sizes.

    25654USD
    ICCT 2019 Table 4

  • Above 2.5 MW of rated site power the ICCT costs no longer hold (new substation or MV connection). The model raises a flag; it does not add the step.

    Market range Single ICCT statement; no independent threshold cited.

    2500kW
    ICCT 2019 p.4

  • Converts the 2019 USD costs (ICCT, NREL) to EUR at the 2019 average rate. No price escalation from 2019 is applied.

    Market range Exact annual average.

    1.1195USD/EUR
    ECB 2019

  • Annual maintenance as a share of the charger purchase price (hardware only, not installation).

    Market range DOE 2015 reports warranty and maintenance contracts of a few hundred USD per year per charger; not converted here.

    1%/year
    NREL LCOC 2020

  • Site communication and back-office fee, converted to EUR at the 2019 ECB rate (536 EUR/yr).

    Market range DOE 2015 (p.21): network fees of 100-900 USD per year.

    600USD/year
    NREL LCOC 2020

  • Used for the reference output 'cost at NREL p2 utilisation'. Cross-check: 0.1172 x 50 kW x 24 h = 141 kWh/d over 17 sessions = 8.3 kWh/session, against 8.2 kWh measured by INL.

    Market range NREL profiles 1.14-20.70 %.

    11.72%
    NREL LCOC 2020 p2

  • Used for the reference output 'cost at NREL p4 utilisation' (busiest NREL hub).

    Market range Busiest NREL profile.

    20.7%
    NREL LCOC 2020 p4

  • Used for the reference output 'cost at NREL p1 utilisation', to show why the model refuses utilisations below 5 %.

    Market range Lowest NREL profile.

    1.14%
    NREL LCOC 2020 p1

  • Independent equipment price for a 150 kW charger, shown converted to EUR next to the ICCT-based model value.

    Market range ICCT 2019 Table 2: 75,000 USD at 150 kW.

    90000USD
    NREL LCOC 2020

  • Independent installation cost for a 150 kW charger, shown converted to EUR. It is about twice the ICCT 3-5-per-site figure (28,312 USD) and above ICCT's single-charger figure (47,781 USD).

    Market range ICCT 2019 Table 4: 18,577-47,781 USD at 150 kW.

    60000USD
    NREL LCOC 2020

  • Published LCOC for the same configuration as the nominal case, at US electricity prices; shown converted to EUR.

    Market range NREL DCFC base: 0.14 (p4) to 0.25 (p2) USD/kWh.

    0.18USD/kWh
    NREL LCOC 2020 p3

  • Lowest published DCFC LCOC; the basis of the 0.12 EUR/kWh lower bound.

    Market range NREL DCFC base 0.14-0.25 USD/kWh.

    0.14USD/kWh
    NREL LCOC 2020 p4

  • Upper end of the published DCFC LCOC at the 'normal' profiles (p1 excluded).

    Market range p1 reaches 1.66-2.19 USD/kWh.

    0.31USD/kWh
    NREL LCOC 2020 p2 high

  • Same configuration as the nominal case (4 x 150 kW, 13.67 %), but at US commercial electricity prices. The model sits above it mainly because of the EU electricity price (0.18 EUR/kWh against roughly 0.10-0.12 USD/kWh in the NREL inputs) and the added demand charge. Not an independent check of the CAPEX: both use ICCT/NREL-family costs.

    Market range Converted single published value.

    0.1608EUR/kWh
    NREL LCOC 2020 converted at ECB 2019

  • Busiest NREL hub (20 x 150 kW, 20.7 %). US electricity prices.

    Market range Converted single published value.

    0.1251EUR/kWh
    NREL LCOC 2020 converted at ECB 2019

  • Single 50 kW urban charger, high-cost scenario. US electricity prices.

    Market range Converted single published value.

    0.2769EUR/kWh
    NREL LCOC 2020 converted at ECB 2019

  • Equipment purchase only, same perimeter as the model's charger purchase price. Comparable at 150 kW only; ICCT gives 66,994 EUR at 150 kW, 17 % lower.

    Market range Converted single published value.

    80393EUR
    NREL LCOC 2020 converted at ECB 2019

  • Installation per charger, same perimeter as the model's installation cost. Comparable at 150 kW only. ICCT's 3-5-per-site figure is about half of it (25,290 EUR); ICCT's single-charger figure (42,680 EUR) is closer. The gap is published, not hidden: use the single-charger case or a quote if your site is not a multi-charger hub.

    Market range Converted single published value.

    53595EUR
    NREL LCOC 2020 converted at ECB 2019

  • Default energy price of the grid electricity bought. Eurostat's non-household price already includes an average share of network charges: adding the demand charge on top double-counts part of it (about 1.7 c/kWh at the nominal case), a conservative choice.

    Market range Eurostat non-household band averages; national values differ widely.

    180EUR/MWh
    Eurostat 2026 S1

  • Default demand (capacity) charge per kW of subscribed power. German DSO tariff for an MV/LV transformer connection at low annual use, the band a charging hub falls in.

    Market range One DSO tariff sheet; other German DSOs publish their own values.

    18.61EUR/kW/year
    Stadtwerke Mosbach 2025

  • Default one-off grid connection contribution per kW of subscribed power (BKZ, BNetzA Leistungspreis model).

    Market range Up to 137.04 EUR/kW at MV (Stadtwerke Elbtal 2026).

    38.46EUR/kW
    enercity Netz 2025

  • High end of the published BKZ values, within the slider range (0-150 EUR/kW).

    Market range 38.46 (enercity, MV/LV) to 137.04 (Elbtal, MV) EUR/kW.

    137.04EUR/kW
    Stadtwerke Elbtal 2026

  • Default service life of the chargers, also exported as the asset lifetime to project mode. DOE's 10 years is the slider minimum.

    Market range 10 (DOE 2015) to 15 years (NREL).

    15years
    NREL LCOC 2020

  • Default real discount rate. Costs are in constant 2019 money (no escalation), so the rate is a real one.

    Market range No independent range cited; slider 0-8 %.

    3.5%
    NREL LCOC 2020

  • Default utilisation: share of the maximum energy (all chargers at full power all year) actually delivered.

    Market range NREL DCFC profiles 1.14-20.70 %.

    13.67%
    NREL LCOC 2020 p3

  • Levelised cost of charging: annualised CAPEX (capital recovery factor) plus yearly fixed costs plus grid electricity, divided by the energy delivered to vehicles. Utilisation is defined, as in NREL, as delivered energy over N x P x 8760.

    Market range Not applicable (method).

    —
    NREL LCOC 2020

  • CAPEX per charger = purchase price (Table 2, log-log in power) + installation (Table 4, by power and by number of chargers per site). The purchase price is hardware only; installation is a separate line. A charger purchase price is never presented as an installed cost.

    Market range Not applicable (method).

    —
    ICCT 2019

  • Grid connection = subscribed power (all chargers at full power, grid side, i.e. divided by the efficiency) x the BKZ per kW. The subscribed power also carries the yearly demand charge.

    Market range Not applicable (method).

    —
    German BKZ practice

  • Convergence note: the Eurostat price already contains an average share of network costs, so adding the demand charge double-counts part of it (about 1.7 c/kWh at the nominal case). It is kept visible as its own cost line so the user can zero it.

    Market range Not applicable (method).

    —
    Eurostat / DSO tariff

  • CAPEX and O&M are 2019 money, not escalated; electricity and grid tariffs are 2025-2026 values. ICCT expects hardware costs to fall about 3 %/year, partly offset by inflation since 2019. Use the Customized option with a current quote for a present-day figure.

    Market range Not applicable (method).

    —
    Currency basis

  • 93 % is the best value measured by the JRC at ambient temperature, on chargers of 50 kW or less; 97-97.5 % are manufacturer peaks. In deep cold the JRC measured down to 39 % at -25 C: the cold-weather output shows the electricity cost per kWh at that efficiency.

    Market range Not applicable (method).

    —
    Efficiency basis

  • Above 2.5 MW of rated site power the CAPEX is an extrapolation: a dedicated substation or MV connection is not priced. The flag output turns to 1.

    Market range Not applicable (method).

    —
    ICCT 2019

  • The CAPEX exported to project mode is an installed cost (purchase + installation + grid connection fee), without contingency or development costs: declared 'installed', so project mode adds working capital and contingency only.

    Market range Not applicable (method).

    —
    Chaining rule