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Modular amine post-combustion CO2 capture unit

Amine capture on industrial flue gas (boiler, cement, incinerator): regeneration heat, electricity, amine make-up, scaled CAPEX and cost of CO2 captured in EUR/t, on the Danish Energy Agency 401.a datasheet, sized in t/d like the CO2 liquefaction calculator.

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Open Jack

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1
  • CurrencyEUR 2025
  • Battery limitfully financed
  • 77 documented assumptions
  • Updated27 Oct 2026

Mass and energy balance

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

Reference case

Share of the year at nameplate capture. Default 90 % is the GCCSI 2025 cost basis. It follows the operation of the emitter.

Flows

  • In: Electricity (capture and compression)—
  • In: LP steam to the reboiler—

Asset

Modular amine post-combustion CO2 capture unit

  • Out: Captured CO2—

Annual quantities at the current usage.

Nameplate CO2 captured per day. Default 768 t/d is the DEA 401.a anchor (32 t/h). The CAPEX follows a 0.6 scale law sourced on built plants of 240 to 4,800 t/d (10-200 t/h, DEA): below 240 t/d, where MHI CO2MPACT (up to 200 t/d) and the smallest CycloneCC trains (from 75 t/d) sit, the law is extrapolated and the result is flagged.

Capture capacity per hour
— t/h
Reboiler heat duty at full load
— MW
Electric load at full load
— MW
CycloneCC trains of 855 t/d
— trains

CAPEX

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

Specific CAPEX at this size

—

Reference size 768 t/d

DEA CCTS p.15, GCCSI 2025 p.27

Model value: the DEA case scaled to the capacity. Customized: your own all-in specific CAPEX (a vendor quote for a modular unit), used as is at every size and no longer sourced.

Specific CAPEX at this size by cO2 capture capacity

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  1. Ex-factory
  2. Installed
  3. Fully financed· this figure
CAPEX at the battery limit—

Included

  • Equipment and installation
  • Indirect and owner's costs
  • Contingency

Not included

  • Nothing

Added at project level

  • Nothing: project mode uses the figure as is

Project figures

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

Concept sketch, not to scale · drag to rotate

Electricity (capture and compression) in
—
LP steam to the reboiler in
—
Captured CO2 outMain product
—
CAPEX to the battery limit
—
Fixed O&M
—
Variable O&M, excluding feedstocks
—
Asset lifetime
25 years

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Cost of CO2 captured

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

—

  • Capture cost - capital—
  • Capture cost - fixed O&M—
  • Capture cost - variable O&M—
  • Capture cost - reboiler steam—
  • Capture cost - electricity—

Linked to the balance above

Share of the year at nameplate capture. Default 90 % is the GCCSI 2025 cost basis. It follows the operation of the emitter.

Included: compression and dehydration to 150 bar for pipeline transport (100 kWh/t, DEA Table 4). Not included: CO2 leaves the stripper near atmospheric pressure, for example to the liquefaction calculator; 0.2 MEUR per t/h is taken off the CAPEX (low end of DEA's 0.2-0.5).

CO2 in the flue gas, %vol. 15 % is the DEA biomass/waste CHP reference; cement kilns run about 20 %, gas turbines 3-4 %. Below 6 % the reboiler heat rises by 15 % (DEA: 10-15 %); above it DEA sees only a marginal effect.

Share of the CO2 in the treated flue gas that is captured. DEA 2025: 90 %. It sets the CO2 left in the flue gas and the flue gas treated; DEA gives no energy or cost law for other rates, so those stay at the 90 % values.

Price of the gas burnt to raise LP steam. Default 60.5 EUR/MWh is the Eurostat EU non-household average for S2 2025. Set 0 if the reboiler runs on waste heat that is genuinely free.

Default 183.7 EUR/MWh is the Eurostat EU non-household average for S2 2025.

Real rate, as a fraction (0.095 = 9.5 %). Costs are in constant EUR. With the DEA 25-year life, 9.5 % gives a CRF of 10.6 %, the value GCCSI 2025 uses for its captured costs.

Cost of CO2 captured by capacity factor

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Benchmarks

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

Regeneration heat, GJ/t

2.1 IEAGHG 2018-TR03 p.45

2.5 DEA CCTS Table 6

2.8 IEAGHG 2018-TR03 p.45

3.5 DEA CCTS Table 6

4.1 IEAGHG 2018-TR03 p.45

Capture-unit electricity, kWh/t

20 DEA CCTS Table 6

40 DEA CCTS Table 6

Compression electricity, kWh/t

90 DEA CCTS Table 4

120 DEA CCTS Table 4

Capital recovery factor (%), %

10.6 GCCSI 2025 p.38

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.

53 outputs · 4 groups · 19 also shown above, dimmed

Cost of CO2 captured

10
Cost of CO2 captured
ComputingEUR/t
Capture cost - capital
ComputingEUR/t
Capture cost - fixed O&M
ComputingEUR/t
Capture cost - variable O&M
ComputingEUR/t
Capture cost - reboiler steam
ComputingEUR/t
Capture cost - electricity
ComputingEUR/t
Cost of CO2 captured with free waste heat
ComputingEUR/t
Energy share of the capture cost
Computing%
LP steam cost
ComputingEUR/GJ
Total annual cost
ComputingEUR/year

Capital and O&M

17
Total CAPEX (all-in, capture + compression)
ComputingEUR
Total CAPEX
ComputingMEUR
Reference specific CAPEX at 768 t/d
ComputingEUR/(t/d)
Specific CAPEX at this size
ComputingEUR/(t/d)
Specific CAPEX at this size (DEA unit)
ComputingMEUR/(t/h)
Specific CAPEX with exponent 0.8
ComputingEUR/(t/d)
Compression CAPEX - low
ComputingMEUR
Compression CAPEX - high
ComputingMEUR
Capital recovery factor
Computing1/year
Capital recovery factor (%)
Computing%
CRF gap to GCCSI 2025
Computing%
Annualised CAPEX
ComputingEUR/year
Fixed O&M
ComputingEUR/year
Variable O&M per t
ComputingEUR/t
Variable O&M
ComputingEUR/year
Steam cost per year
ComputingEUR/year
Electricity cost per year
ComputingEUR/year

Energy

15
Regeneration heat
ComputingGJ/t
Regeneration heat before low-CO2 penalty
ComputingGJ/t
Low-CO2 heat penalty
Computing%
Dilute flue gas
Computingbool
Specific electricity
ComputingkWh/t
Capture-unit electricity
ComputingkWh/t
Compression electricity
ComputingkWh/t
Compression electricity - GCCSI cross-check
ComputingkWh/t
Total energy use per t
ComputingGJ/t
Reboiler heat per year
ComputingGJ/year
Reboiler heat per year (MWh)
ComputingMWh/year
Electricity per year
ComputingMWh/year
Reboiler heat duty at full load
ComputingMW
Electric load at full load
ComputingMW
Low-grade heat rejected
ComputingGJ/year

Mass balance and sizing

11
Capture capacity per hour
Computingt/h
Equivalent full-load hours
Computingh/year
CO2 captured per year
Computingt/year
CO2 in the treated flue gas
Computingt/year
CO2 left in the flue gas
Computingt/year
Flue gas treated per t captured
Computingt/t
Flue gas treated per year
Computingt/year
Amine make-up
Computingkg/t
Amine make-up per year
Computingt/year
Outside the sourced size range
Computingbool
CycloneCC trains of 855 t/d
Computingtrains

Sensitivities

5 charts
Cost of CO2 captured vs capacity factor

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Cost and specific CAPEX vs capacity (sourced range 240-1,000 t/d)

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Cost of CO2 captured vs gas price for steam

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Regeneration heat vs flue gas CO2 content

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Cost of CO2 captured vs electricity price

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Sources

77 documented assumptions · 6 sources

About

Calculator context

A screening model of a post-combustion amine capture unit on industrial flue gas (biomass or waste boiler, cement kiln, incinerator), built for a feasibility study that has to stand in front of a lender. Every number comes from one dated public catalogue, the Danish Energy Agency and Energinet datasheet 401.a 'Post comb - small CHP' (2025 estimate), whose three columns (estimate, lower, upper) are the three reference cases: specific investment 5.9 / 3.54 / 8.26 MEUR per t CO2/h at 32 t/h, reboiler steam 0.833 / 0.66 / 1.0 MWh/t, capture electricity 30 / 25 / 35 kWh/t, variable O&M 2.5 / 1.5 / 3.5 EUR/t with the amine make-up inside, fixed O&M 3 % of CAPEX, 25-year life. The DEA scope includes liquefaction; this calculator stops at 150 bar compression (100 kWh/t, DEA Table 4) and removes the 0.2 MEUR per t/h DEA gives for that difference (note J). Liquefaction is the separate calculator, chained on the same t/d.

The size is the CO2 captured per day. The CAPEX follows a 0.6 scale law (DEA: 0.6-0.7; GCCSI 2025: 0.6-0.8) from the 768 t/d anchor. DEA reports built plants of 10-200 t/h, so the law is sourced from 240 t/d upward; between 1 and 240 t/d, where MHI CO2MPACT and the smallest CycloneCC trains sit, it is extrapolated, the 'Outside the sourced size range' flag is raised and the charts stop at 240 t/d. A vendor quote goes in as a Customized CAPEX. The reboiler duty rises by 15 % below 6 %vol CO2 in the flue gas (DEA: 10-15 % at 3-4 %), and is otherwise flat with CO2 content, as DEA states.

At the DEA central case and 768 t/d, 90 % capacity factor, compression on, EU non-household gas (60.5 EUR/MWh, Eurostat S2 2025) and electricity (183.7 EUR/MWh), the cost of CO2 captured is 183.5 EUR/t: 76.6 capital, 21.7 fixed O&M, 2.5 variable O&M, 58.8 steam (3.0 GJ/t at 19.6 EUR/GJ from an 85.7 % gas boiler) and 23.9 electricity (130 kWh/t). The CAPEX is 182.4 MEUR. The annuity uses a 9.5 % real rate over 25 years, a CRF of 10.60 %, the 10.6 % GCCSI 2025 uses. With free waste heat the cost falls to 124.7 EUR/t. At the DEA upper column, 240 t/d and a 3 %vol flue gas it is 334.5 EUR/t.

Read it with its limits: a cost per tonne captured, not avoided (the CO2 of the steam and power is not deducted); constant prices; the capture rate changes the CO2 left in the flue gas and the gas treated, not the energy or CAPEX per tonne, since DEA gives no law for other rates; the blower power is not re-scaled with the flue gas volume. The CAPEX is the DEA all-in figure and is exported as fully financed, so project mode adds no further cost layer.

Model

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

127 variables shown of 127
VariableValueUnitDepends on
768t/d—
90%—
1——
0——
237500EUR/(t/d)—
1——
15%—
90%—
60.5EUR/MWh—
183.7EUR/MWh—
0.095ratio—
VariableFormulaUnitDepends on
if((<=)+(<=)+(>)+(!=)*(!=)*(!=)+(<)+(>)+(>=)*(<=)+(<=)+(>)+(<=)+(>)+(<)+(>)+(<)+(<)+(<)+(>=)>,,)bool
if(==,,if(==,,))--(-)*MEUR/(t/h)
if(>=,,)—
if(>=,,)EUR/(t/d)
VariableFormulaUnitDepends on
/t/h
**h/year
*t/year
/max(*,)t/year
-t/year
*(/max(,))*(/max(,))t/t
*t/year
if(<,,)bool
*%
if(==,,if(==,,))*GJ/t
*(+*)GJ/t
if(==,,if(==,,))kWh/t
*if(==,,if(==,,))kWh/t
+kWh/t
+*GJ/t
*GJ/year
/MWh/year
**MWh/year
*/MW
**MW
*GJ/year
if(==,,if(==,,))kg/t
**t/year
*/EUR/(t/d)
clamp(*(/)^(-),,)EUR/(t/d)
*/MEUR/(t/h)
*(/)^(-)EUR/(t/d)
*EUR
/MEUR
**MEUR
**MEUR
if(<,/,(*(+)^)/max((+)^-,))1/year
*%
-%
*EUR/year
**EUR/year
if(==,,if(==,,))EUR/t
*EUR/year
/max(*,)/EUR/GJ
*EUR/year
*EUR/year
/max(,)EUR/t
/max(,)EUR/t
/max(,)EUR/t
/max(,)EUR/t
/max(,)EUR/t
++++EUR/t
++++EUR/year
(+)/max(,)*%
-EUR/t
if((<)+(>*)>,,)bool
ceil(/)trains
*/kWh/t

Assumptions

77 assumptions used in the calculations

  • Protects divisions against a zero denominator; small enough to leave every result unchanged.

    Market range Not applicable (numerical or unit constant).

    0.000001
    Numerical constant

  • Literal zero for guards and flags, so no number is written inline.

    Market range Not applicable (numerical or unit constant).

    0
    Numerical constant

  • Literal one for flags, the CRF and multipliers.

    Market range Not applicable (numerical or unit constant).

    1
    Numerical constant

  • Converts a percent input (0-100) to a fraction.

    Market range Not applicable (numerical or unit constant).

    0.01
    Numerical constant

  • Converts a fraction to percent.

    Market range Not applicable (numerical or unit constant).

    100%
    Numerical constant

  • Converts t/d to t/h (and M EUR per t/h to EUR per t/d).

    Market range Not applicable (numerical or unit constant).

    24h/d
    Numerical constant

  • Hours in a non-leap year; base of the load hours.

    Market range Not applicable (numerical or unit constant).

    8760h/year
    Numerical constant

  • Days in a non-leap year.

    Market range Not applicable (numerical or unit constant).

    365d/year
    Numerical constant

  • 1 MWh = 3.6 GJ (DEA prints heat in MWh/t, this calculator shows GJ/t).

    Market range Not applicable (numerical or unit constant).

    3.6GJ/MWh
    Numerical constant

  • 1 kWh = 0.0036 GJ.

    Market range Not applicable (numerical or unit constant).

    0.0036GJ/kWh
    Numerical constant

  • 1 kWh = 0.001 MWh.

    Market range Not applicable (numerical or unit constant).

    0.001MWh/kWh
    Numerical constant

  • 1 kg = 0.001 t.

    Market range Not applicable (numerical or unit constant).

    0.001t/kg
    Numerical constant

  • 1 million EUR.

    Market range Not applicable (numerical or unit constant).

    1000000EUR/MEUR
    Numerical constant

  • Integer id of the reference case 'DEA 401.a 2025 central estimate' in the technology_case select; no string in the DSL.

    Market range Not applicable (selector).

    1
    Selector id

  • Integer id of the reference case 'DEA 401.a 2025 lower column' in the technology_case select; no string in the DSL.

    Market range Not applicable (selector).

    2
    Selector id

  • Integer id of the reference case 'DEA 401.a 2025 upper column' in the technology_case select; no string in the DSL.

    Market range Not applicable (selector).

    3
    Selector id

  • Size of the DEA cost anchor. The sourced specific investment is per (t CO2/h) at this size.

    Market range Single anchor size in the datasheet.

    32t/h
    DEA Technology Data CCTS, datasheet 401.a

  • Reference size of the CAPEX scale law, in the size unit of the slider (t/d). Also the default size.

    Market range Single anchor size in the datasheet.

    768t/d
    DEA datasheet 401.a, converted to t/d

  • CAPEX = C_ref x (size / 768 t/d)^0.6, so the specific CAPEX per t/d scales with exponent 0.6 - 1 = -0.4. 0.6 is the low end of both sources: it gives the strongest economy of scale, hence the highest specific cost for small modules. DEA states the law for the whole plant; it does not give a separate exponent for compact or modular units.

    0.6
    DEA CCTS p.15, GCCSI 2025 p.27

  • Upper end of the GCCSI exponent band. Used only in the 'specific CAPEX at exponent 0.8' check output, to show how much the small-module cost depends on the exponent.

    0.8
    GCCSI 2025 p.27

  • Lower edge of the size range DEA reports for built plants. Below it the 0.6 scale law is extrapolated: no public source found covers the CAPEX of amine modules below 10 t/h.

    10t/h
    DEA CCTS p.37

  • Upper edge of the DEA size range (4,800 t/d), above the slider maximum.

    200t/h
    DEA CCTS p.37

  • Below 240 t/d the out-of-sourced-domain flag is raised and the CAPEX is an extrapolation of the 0.6 law.

    Market range 10 t/h = 240 t/d.

    240t/d
    DEA CCTS p.37, converted to t/d

  • Lower clamp of the scaled specific CAPEX. Far below any value the law reaches on the 1-1,000 t/d slider (the lowest is about 118,000 EUR/(t/d), at 1,000 t/d in the DEA lower case without compression), so it never binds inside the slider range; it only stops a non-physical value outside it.

    Market range Not applicable (guard).

    1000EUR/(t/d)
    Numerical guard

  • Upper clamp of the scaled specific CAPEX. Above the highest value the law reaches on the slider (about 4.8 million EUR/(t/d) at 1 t/d in the DEA upper case), so it never binds inside the slider range.

    Market range Not applicable (guard).

    100000000EUR/(t/d)
    Numerical guard

  • Central DEA specific investment. Scope includes liquefaction, which this calculator does not (liquefaction is the separate chainable calculator), so note J's 0.2 is removed.

    Market range Lower 3.54, upper 8.26 MEUR/(t/h) (same sheet).

    5.9MEUR/(t/h)
    DEA datasheet 401.a

  • Specific investment of the 'DEA lower' reference case, before removing liquefaction.

    3.54MEUR/(t/h)
    DEA datasheet 401.a

  • Specific investment of the 'DEA upper' reference case, before removing liquefaction.

    8.26MEUR/(t/h)
    DEA datasheet 401.a

  • Removed from every DEA case: the scope of this calculator stops at 150 bar compression (or at the stripper outlet if compression is off). 5.9 - 0.2 = 5.7 MEUR/(t/h) capture + compression.

    Market range Single value in note J.

    0.2MEUR/(t/h)
    DEA datasheet 401.a note J

  • Removed when compression is switched off. The low end of the DEA range is taken so as not to over-deduct: the DEA plant cost already integrates compression with the capture unit and its share is not split in the datasheet.

    0.2MEUR/(t/h)
    DEA CCTS Table 4

  • Upper end of the compression CAPEX range, shown in the compression CAPEX range output.

    0.5MEUR/(t/h)
    DEA CCTS Table 4

  • Fixed O&M per year = 3 % of the CAPEX, in every reference case.

    Market range Single value (DEA).

    3%
    DEA CCTS p.49

  • Variable O&M of the central case. It contains the amine make-up (about 2 EUR/t) and small consumables (0.5 EUR/t, DEA p.49); amine is therefore not counted again.

    2.5EUR/t
    DEA datasheet 401.a

  • Variable O&M of the 'DEA lower' case.

    1.5EUR/t
    DEA datasheet 401.a

  • Variable O&M of the 'DEA upper' case.

    3.5EUR/t
    DEA datasheet 401.a

  • Part of the central variable O&M that is amine make-up. Documents why amine is not costed a second time; not added to the cost.

    Market range Not split for the lower/upper columns.

    2EUR/t
    DEA CCTS p.49

  • Solvent make-up for degradation and losses, central case. Information only (its cost sits in variable O&M).

    0.3kg/t
    DEA datasheet 401.a

  • Solvent make-up of the 'DEA lower' case.

    0.15kg/t
    DEA datasheet 401.a

  • Solvent make-up of the 'DEA upper' case (MEA-like degradation).

    1.5kg/t
    DEA datasheet 401.a

  • Reboiler LP steam per t of CO2 captured, central case (0.833 x 3.6 = 3.0 GJ/t), for a flue gas with 15 %vol CO2.

    0.833MWh/t
    DEA datasheet 401.a

  • Reboiler heat of the 'DEA lower' case (2.38 GJ/t).

    0.66MWh/t
    DEA datasheet 401.a

  • Reboiler heat of the 'DEA upper' case (3.6 GJ/t).

    1MWh/t
    DEA datasheet 401.a

  • Below 6 %vol CO2 in the flue gas the low-CO2 penalty applies. DEA documents a step between two regimes, not a continuous law, so the model uses a step at the low end of the 6-8 % band.

    6%
    DEA CCTS p.32

  • Low end of the DEA low-CO2 penalty; shown in the penalty range, not used in the cost.

    10%
    DEA CCTS p.32

  • Penalty applied to the reboiler heat when the flue gas is below 6 %vol CO2. The high end is used so that a dilute stream is not under-costed in front of a lender.

    15%
    DEA CCTS p.32

  • Benchmark: low end of the DEA technology-chapter range for the reboiler duty.

    2.5GJ/t
    DEA CCTS Table 6

  • Benchmark: high end of the DEA technology-chapter range.

    3.5GJ/t
    DEA CCTS Table 6

  • Benchmark: low end of the MEA reboiler duty in an independent source.

    2.8GJ/t
    IEAGHG 2018-TR03 p.45

  • Benchmark: high end of the MEA reboiler duty (older MEA plants).

    4.1GJ/t
    IEAGHG 2018-TR03 p.45

  • Benchmark: best advanced-amine reboiler duty reported by IEAGHG.

    Market range 2.1 GJ/t (advanced amine).

    2.1GJ/t
    IEAGHG 2018-TR03 p.45

  • Capture-unit electricity of the central case, without compression.

    30kWh/t
    DEA datasheet 401.a

  • Capture-unit electricity of the 'DEA lower' case.

    25kWh/t
    DEA datasheet 401.a

  • Capture-unit electricity of the 'DEA upper' case.

    35kWh/t
    DEA datasheet 401.a

  • Benchmark: low end of the DEA technology-chapter range for capture electricity.

    20kWh/t
    DEA CCTS Table 6

  • Benchmark: high end of the DEA technology-chapter range for capture electricity.

    40kWh/t
    DEA CCTS Table 6

  • Compression and dehydration to 150 bar, central case; added when compression is on.

    100kWh/t
    DEA CCTS Table 4

  • Compression electricity of the 'DEA lower' case.

    90kWh/t
    DEA CCTS Table 4

  • Compression electricity of the 'DEA upper' case.

    120kWh/t
    DEA CCTS Table 4

  • Independent cross-check of the DEA compression figure. Converted by this calculator (not printed by GCCSI): 3,784 kW x 24 h / 1,000 t = 90.8 kWh/t, at the low end of the DEA 90-120.

    Market range Single design point.

    3784kW
    GCCSI 2025 Table 4

  • Capacity at which GCCSI gives the compressor power; used only to convert it to kWh/t.

    Market range Single design point.

    1000t/d
    GCCSI 2025 Table 4

  • Capture rate at which DEA gives its flue gas mass per t captured; reference of the flue gas scaling. The capture-rate slider defaults to it.

    Market range 90 % (DEA 2025); 85-95 % on the slider.

    90%
    DEA datasheet 401.a

  • Flue gas CO2 concentration of the DEA reference; reference of the flue gas scaling and the slider default.

    15%
    DEA datasheet 401.a

  • Flue gas treated per t captured at the DEA reference. Scaled by 15 / CO2 %vol and 90 / capture rate: at a constant mean molar mass of the flue gas, the mass of gas per t of CO2 is inversely proportional to the CO2 volume fraction. Information only; the blower electricity is not re-scaled (DEA gives no split).

    Market range Single value at 15 %vol.

    5.1t/t
    DEA datasheet 401.a

  • Default of the capacity factor slider (also used to read the GCCSI cost basis).

    90%
    GCCSI 2025 p.38

  • Physical service life of the capture plant; annuity period of the CRF and lifetime exported to project mode.

    Market range 25 years (DEA).

    25years
    DEA datasheet 401.a

  • Benchmark of the CRF. GCCSI does not state the rate and the period in the quoted text; this calculator computes its own CRF from the discount rate and the DEA 25-year life, and shows the gap to 10.6 %.

    Market range Single value (GCCSI).

    10.6%
    GCCSI 2025 p.38

  • Default real discount rate 9.5 %: over the DEA 25 years it gives a CRF of 10.60 %, the GCCSI value. This is a calibration of one free parameter on one published factor, declared as such. All costs are in constant EUR with no escalation, so the rate is read as real.

    Market range 0-12 % on the slider.

    —
    Calibrated on GCCSI 2025

  • Default of the gas price slider (60.5 EUR/MWh).

    Market range EU non-household average; national prices vary widely.

    0.0605EUR/kWh
    Eurostat

  • Default of the electricity price slider (183.7 EUR/MWh).

    Market range EU non-household average; large consumers often pay less.

    0.1837EUR/kWh
    Eurostat

  • Converts the gas price to a steam cost: EUR/GJ steam = gas price / 0.857 / 3.6. At 60.5 EUR/MWh gas the steam costs 19.6 EUR/GJ. Set the gas price to 0 for genuinely free waste heat.

    Market range Single benchmark value.

    85.7%
    DOE Steam Tip Sheet #15

  • Catalog product: largest CO2MPACT size, inside the extrapolated range (below 240 t/d).

    200t/d
    MHI 2024

  • Catalog product: smallest CycloneCC train, inside the extrapolated range.

    75t/d
    Carbon Clean

  • Largest CycloneCC train; used to count how many trains of that size the capacity needs.

    855t/d
    Carbon Clean

  • Cost of CO2 captured = (CAPEX x CRF + fixed O&M) / t captured per year + variable O&M + reboiler heat x steam cost + electricity x price. It is a captured cost, not an avoided cost: the CO2 emitted to make the steam and electricity is not deducted.

    Market range Not applicable (method).

    —
    DEA 401.a, GCCSI 2025

  • Scope: capture unit with flue gas pre-treatment, utilities, cooling water and optional compression and dehydration to 150 bar. Liquefaction (about 0.16 MWh/t), transport and storage are outside; flue gas desulphurisation upstream is assumed done by the host.

    Market range Not applicable (scope).

    —
    DEA 401.a

  • Between 1 and 240 t/d the 0.6 law is extrapolated below the smallest DEA plant size, where the catalog products sit (MHI CO2MPACT up to 200 t/d, CycloneCC from 75 t/d). The flag 'Outside the sourced size range' is raised and the charts are drawn on 240-1,000 t/d only. Packaged modular units may cost less than this extrapolation suggests; a vendor quote belongs in the Customized CAPEX.

    Market range Not applicable (limit).

    —
    DEA CCTS p.37

  • The reboiler duty only responds to the flue gas CO2 through the documented low-CO2 step (below 6 %vol). The capture rate changes the CO2 in the flue gas and the flue gas mass, not the energy or the CAPEX per t captured: DEA gives no law for capture rates other than 90 %.

    Market range Not applicable (limit).

    —
    DEA CCTS p.32