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Bio-LNG production: biogas upgrading and small-scale liquefaction levelized cost

Raw biogas to bio-LNG: membrane upgrading, CO2 polishing to 50 ppm and containerised liquefaction. Bio-LNG in t/yr and t/d, kWh per kg, CO2 co-product, CAPEX on a 0.6 law (DEA, Naerenergi), cost in EUR/MWh HHV with and without biogas.

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Open Jack

Founder · OpenJack

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  • CurrencyEUR 2019
  • Battery limitex-factory
  • 79 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 the chain runs at its nameplate flow. 95 % is the MMMCZCS assumption for upgrading and liquefaction units. Sets the yearly tonnes; the CAPEX depends on the nameplate flow only.

Flows

  • In: Raw biogas—
  • In: Electricity—

Asset

Small-scale bio-LNG plant: membrane upgrading, CO2 polishing and liquefaction

  • Out: Bio-LNG—
  • Out: CO2 in the upgrading off-gas (contained, not liquefied)—

Annual quantities at the current usage.

Raw biogas entering the upgrading, in Nm3/h (0 C, 1 atm). Size marks: Cryo Pur Omagh 300 and Stord 700 Nm3/h of raw biogas. Makers of liquefiers print LNG in t/d (Bright LiquiPac 5-25 t/d), shown next to this input.

Bio-LNG nameplate output
— t/d
Biomethane flow
— Nm3/h
Electrical demand
— MW

CAPEX

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

Specific CAPEX at this size

—

Reference size 1,000 Nm3/h

Published value

Model value: DEA upgrading plus Naerenergi liquefaction, scaled with the 0.6 rule. Customized: your own quote per Nm3/h of raw biogas, used as is at every size; the value is then no longer sourced.

Specific CAPEX by raw biogas flow

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

Included

  • Equipment as delivered by the manufacturer

Not included

  • Installation, piping and electrical works
  • Civil works, buildings and land
  • Engineering and construction
  • Contingency

Added at project level

  • Every installation and indirect cost 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

Raw biogas in
—
Electricity in
—
Bio-LNG outMain product
—
CO2 in the upgrading off-gas (contained, not liquefied) out
—
CAPEX to the battery limit
—
Fixed O&M
—
Variable O&M, excluding feedstocks
—
Asset lifetime
20 years

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Bio-LNG production cost

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

—

  • Cost: capital—
  • Cost: upgrading fixed O&M—
  • Cost: liquefier service—
  • Cost: electricity—
  • Cost: raw biogas—

Linked to the balance above

Share of the year the chain runs at its nameplate flow. 95 % is the MMMCZCS assumption for upgrading and liquefaction units. Sets the yearly tonnes; the CAPEX depends on the nameplate flow only.

CH4 share of the raw biogas by volume, the rest taken as CO2. DEA gives 50-70 %; 60 % is the midpoint of that range, not a printed value.

Price of the electricity used by the upgrading compressors and the liquefier. 55 EUR/MWh is the MMMCZCS assumption.

Cost of the raw biogas per MWh of methane it carries (LHV). 80 EUR/MWh is the MMMCZCS value for a plant of about 500 Nm3/h, falling to 50 EUR/MWh at 10,000 Nm3/h. The cost without biogas is shown separately.

Real rate for the capital recovery factor. 7 % is the MMMCZCS assumption.

Years over which the investment is annualised. 20 years is the MMMCZCS plant design life.

Bio-LNG production cost by availability

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Benchmarks

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

Liquefaction electricity, kWh/kg

0.7 Published value

0.82 Published value

1 Published value

Specific electricity, kWh/kg

1.45 Published value

Whole-chain electricity per Nm3, kWh/Nm3

0.57 Published value

0.72 Published value

Upgrading electricity, kWh/Nm3

0.2 Published value

0.3 Published value

Methane loss, %

0.5 Published value

2 Published value

Raw biogas share of cost, %

50 Published value

70 Published value

Production cost on LHV, EUR/MWh

120 Published value

130 Published value

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.

58 outputs · 6 groups · 24 also shown above, dimmed

Bio-LNG cost

12
Bio-LNG production cost
ComputingEUR/MWh
Production cost without biogas
ComputingEUR/MWh
Bio-LNG production cost per tonne
ComputingEUR/t
Cost per tonne without biogas
ComputingEUR/t
Cost: capital
ComputingEUR/MWh
Cost: upgrading fixed O&M
ComputingEUR/MWh
Cost: liquefier service
ComputingEUR/MWh
Cost: electricity
ComputingEUR/MWh
Cost: raw biogas
ComputingEUR/MWh
Raw biogas share of cost
Computing%
Production cost on LHV
ComputingEUR/MWh
Cost without biogas on LHV
ComputingEUR/MWh

Size and CAPEX

10
Total CAPEX
ComputingEUR
CAPEX: upgrading
ComputingEUR
CAPEX: liquefier
ComputingEUR
Specific CAPEX
ComputingEUR/(Nm3/h)
Specific CAPEX at 1,000 Nm3/h
ComputingEUR/(Nm3/h)
CAPEX at 1,000 Nm3/h
ComputingEUR
Scaling exponent applied
Computingratio
Upgrading share of CAPEX
Computing%
CAPEX per t/d of LNG
ComputingEUR/(t/d)
Liquefier size outside the budget points
Computingbool

Mass balance

12
Bio-LNG produced
Computingt/yr
Bio-LNG nameplate output
Computingt/d
Bio-LNG flow
Computingkg/h
Biomethane flow
ComputingNm3/h
Methane recovery
Computing%
Methane loss
Computing%
Methane slip
Computingt/yr
CO2 co-product (contained)
Computingt/yr
CO2 spec before the cold box
Computingppm
Bio-LNG energy per year
ComputingMWh/yr
Raw biogas energy per year
ComputingMWh/yr
Operating hours
Computingh/year

Electricity and losses

11
Specific electricity
ComputingkWh/kg
Liquefaction electricity
ComputingkWh/kg
Upgrading electricity per kg
ComputingkWh/kg
Upgrading electricity
ComputingkWh/Nm3
Whole-chain electricity per Nm3
ComputingkWh/Nm3
Gap to best liquefier
Computing%
Electrical demand
ComputingMW
Electricity per year
ComputingMWh/yr
Upgrading electricity per year
ComputingMWh/yr
Liquefaction electricity per year
ComputingMWh/yr
Heat and losses
ComputingMWh/yr

Source checks

6
Law vs budget at 40 kg/h
Computing%
Law vs budget at 120 kg/h
Computing%
Law vs budget at 610 kg/h
Computing%
Liquefaction slice at Capra's plant
ComputingEUR/MWh
Capra liquefaction cost
ComputingEUR/MWh
Gap to Capra
Computing%

Finance and yearly costs

7
Capital recovery factor
Computing1/year
Annualised CAPEX
ComputingEUR/year
Upgrading fixed O&M
ComputingEUR/year
Liquefier service
ComputingEUR/year
Electricity cost
ComputingEUR/year
Raw biogas cost
ComputingEUR/year
Total yearly cost
ComputingEUR/year

Sensitivities

5 charts
Bio-LNG cost components vs availability

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Specific CAPEX and cost without biogas vs raw biogas flow

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Specific electricity by reference liquefier

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Bio-LNG and CO2 co-product vs raw biogas flow

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Bio-LNG cost vs electricity price

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Sources

79 documented assumptions · 10 sources

About

Calculator context

Small bio-LNG plant that turns raw biogas into liquefied biomethane for trucks and ships: membrane upgrading with H2S and water pre-treatment, CO2 polishing to the liquefaction spec (CO2 50 ppm, H2S 4 ppm, water 1 ppm), then a containerised liquefier of the mixed-refrigerant or nitrogen-expander class. The size input is the raw biogas flow in Nm3/h (100 to 3,000); the page also gives the nameplate LNG output in t/d, the unit liquefier makers print. Outputs: bio-LNG in t/yr and t/d, biomethane flow, methane recovery and slip, CO2 contained in the off-gas, whole-chain electricity in kWh per kg of LNG and per Nm3 of raw biogas, CAPEX split between upgrading and liquefier, and the production cost in EUR per MWh HHV (PCS) and per tonne, with and without the raw biogas.

Method. Mass balance on methane: CH4 in the raw biogas times the membrane recovery (99.5 %, Bright Renewables) gives the biomethane, taken as pure methane at 0.717 kg/Nm3. Electricity: 0.22 kWh per Nm3 of raw biogas for the upgrading (Bright; DEA gives 0.2-0.3) plus the liquefier figure of the chosen reference case (0.70 to 1.0 kWh/kg, Bright and Naerenergi). CAPEX: the DEA 2017 upgrading investment (302,000 EUR per MJ/s of input at 1,000 Nm3/h) and the Naerenergi budget of a 200 kg/h liquefier (2.8 MEUR), each scaled with the 0.6 rule used by MMMCZCS 2022. The cost is levelised with the MMMCZCS assumptions: 7 % real, 20 years, 95 % availability, 55 EUR/MWh electricity, raw biogas at 80 EUR/MWh LHV.

Checks. The 0.6 law falls within 7 % of the Naerenergi budgets at 40 and 120 kg/h, and overestimates the 610 kg/h Cryobox 600 by 9 % against the top of its 4.5-5.0 MEUR range; above 610 kg/h of LNG (about 1,400 Nm3/h of raw biogas at 60 % CH4) the liquefier cost is extrapolated. At Capra et al.'s plant (4.6 t/d, 0.85 kWh/kg) the model's liquefaction slice is about 30 % below their 6.3 EUR/GJ LHV. Without biogas the model is also below the 38-63 EUR/MWh LHV implied by MMMCZCS for upgrading and liquefaction, because it leaves out LNG storage, loading, civil works and LNG transfer. These gaps are published as outputs, not tuned away.

Scope. LNG buffer storage, loading and civil works are excluded, as in the Naerenergi budgets. Integrated cryogenic upgrading (Cryo Pur type), heat recovery, CO2 liquefaction and off-gas treatment are not modelled. The CO2 output is the CO2 contained in the off-gas, an upper bound for a liquid CO2 sale.

Model

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

149 variables shown of 149
VariableValueUnitDepends on
1000Nm3/h—
60%—
1——
95%—
0——
6000EUR/(Nm3/h)—
55EUR/MWh—
80EUR/MWh—
7%—
20years—
VariableFormulaUnitDepends on
if((<=)+(<)+(>)+(<=)+(>/)+(<)+(>)+(<)+(>)+(<=)+(<)+(<)+(<)+(<=)>,,)bool
**Nm3/h
*(-*)Nm3/h
(-)*kg/h
**/MWh/yr
*kW
*kW
+kW
**/MWh/yr
**/MJ/s
**(/)^EUR
*(/)^EUR
****/MJ/s
*****kg/h
*ratio
*/kg/h
/kWh/kg
VariableFormulaUnitDepends on
**h/year
**Nm3/h
/max(,)/%
/-%
*kg/h
**t/d
**t/yr
**/MWh/yr
***/MWh/yr
***t/yr
**t/yr
ppm
kWh/Nm3
if(==,,if(==,,if(==,,)))kWh/kg
(/-)/%
*MW
/max(,)kWh/kg
/max(,)kWh/kg
/max(,)kWh/Nm3
**MWh/yr
**MWh/yr
+MWh/yr
+MWh/yr
**(/)^+*(/)^EUR
/EUR/(Nm3/h)
if(>=,,)ratio
if(>=,,clamp(*(/)^(-),,))EUR/(Nm3/h)
*EUR
/max(+,)/%
**EUR
-EUR
/max(,)EUR/(t/d)
if((<)+(>)>,,)bool
(*(/)^/-)/%
(*(/)^/-)/%
(*(/)^/-)/%
if(<,/,(*(+)^)/max((+)^-,))1/year
*EUR/year
*EUR/year
**EUR/year
*EUR/year
*EUR/year
++++EUR/year
/max(,)EUR/MWh
/max(,)EUR/MWh
/max(,)EUR/MWh
/max(,)EUR/MWh
/max(,)EUR/MWh
+++EUR/MWh
+EUR/MWh
/max(,)EUR/t
(-)/max(,)EUR/t
/max(,)EUR/MWh
(-)/max(,)EUR/MWh
/max(,)/%
(*(/)^*+(+**)**)/max(**/,)EUR/MWh
*EUR/MWh
(/max(,)-)/%

Assumptions

79 assumptions used in the calculations

  • Protects divisions against a zero denominator.

    Market range Not applicable (numerical parameter).

    0.000001
    Numerical constant

  • Unit value used in the CRF, the guards and the Customized switch.

    Market range Exact by definition.

    1
    Numerical constant

  • Zero used in the guards.

    Market range Exact by definition.

    0
    Numerical constant

  • Turns a percentage into a fraction.

    Market range Exact by definition.

    0.011/%
    Numerical constant

  • Kilograms to tonnes.

    Market range Exact by definition.

    0.001t/kg
    Numerical constant

  • Tonnes to kilograms.

    Market range Exact by definition.

    1000kg/t
    Numerical constant

  • Kilowatt-hours to megawatt-hours.

    Market range Exact by definition.

    0.001MWh/kWh
    Numerical constant

  • Kilowatts to megawatts.

    Market range Exact by definition.

    0.001MW/kW
    Numerical constant

  • Hours in a non-leap year.

    Market range Exact by definition.

    8760h/year
    Numerical constant

  • Hours in a day.

    Market range Exact by definition.

    24h/d
    Numerical constant

  • Seconds in an hour; turns MJ/h into MJ/s.

    Market range Exact by definition.

    3600s/h
    Numerical constant

  • 1 MWh = 3,600 MJ.

    Market range Exact by definition.

    3600MJ/MWh
    Numerical constant

  • 1 kWh = 3,600 kJ; turns Capra's 3,061 kJ/kg into kWh/kg.

    Market range Exact by definition.

    3600kJ/kWh
    Numerical constant

  • 1 MWh = 3.6 GJ; turns Capra's EUR/GJ into EUR/MWh.

    Market range Exact by definition.

    3.6GJ/MWh
    Numerical constant

  • Reference case 1: Naerenergi Cryobox 600, 0.82 kWh/kg (Naerenergi 2019, slide 16).

    Market range Not applicable (selector code).

    1
    Numerical constant

  • Reference case 2: Bright Renewables LiquiPac, 0.70 kWh/kg (manufacturer page).

    Market range Not applicable (selector code).

    2
    Numerical constant

  • Reference case 3: Naerenergi micro system 200 kg/h, 0.90 kWh/kg (Naerenergi 2019, slide 18).

    Market range Not applicable (selector code).

    3
    Numerical constant

  • Reference case 4: Naerenergi micro system 40 kg/h, 1.0 kWh/kg (Naerenergi 2019, slide 18).

    Market range Not applicable (selector code).

    4
    Numerical constant

  • Lowest valid case code.

    Market range Not applicable (selector code).

    1
    Numerical constant

  • Highest valid case code.

    Market range Not applicable (selector code).

    4
    Numerical constant

  • Turns methane volume (Nm3, 0 C, 1 atm) into mass. Bio-LNG is treated as pure methane (LiquiPac purity above 98 %).

    Market range Fixed physical property.

    0.717kg/Nm3
    Published value

  • Turns the CO2 volume of the raw biogas into the mass of CO2 contained in the off-gas.

    Market range Fixed physical property.

    1.977kg/Nm3
    Published value

  • Energy content of the bio-LNG on the gross (HHV, PCS) basis used for the headline cost in EUR/MWh.

    Market range Fixed physical property; 13.9 kWh/kg LHV, 15.4 kWh/kg HHV.

    55.5MJ/kg
    Published value

  • Net basis: prices the raw biogas (EUR/MWh LHV, as MMMCZCS quotes it), sizes the upgrading on its input power and gives the LHV cost for comparison with MMMCZCS and Capra.

    Market range Fixed physical property.

    50MJ/kg
    Published value

  • Lower edge of the CH4 content slider and of the valid domain.

    Market range DEA: 50-70 %.

    50%
    Published value

  • Upper edge of the CH4 content slider and of the valid domain.

    Market range DEA: 50-70 %.

    70%
    Published value

  • Share of the CH4 in the raw biogas that leaves the membrane upgrading as biomethane; the rest is lost in the off-gas (methane slip).

    Market range IEA Bioenergy Task 37 (Persson 2013) gives 0.5-2 % methane loss for membranes, i.e. 98-99.5 % recovery; 99.5 % is the best value of that range.

    99.5%
    Published value

  • Low end of the published membrane methane loss, compared with the model's loss.

    0.5%
    Published value

  • High end of the published membrane methane loss, compared with the model's loss.

    2%
    Published value

  • Electricity of the membrane upgrading per Nm3 of raw biogas, pre-treatment (H2S, water) included in the block.

    Market range DEA 2017 and IEA Task 37 (Persson 2013): 0.20-0.30 kWh/Nm3 raw biogas for membranes; 0.22 is a manufacturer figure near the low end.

    0.22kWh/Nm3
    Published value

  • Low end of the published upgrading electricity, compared with the model value.

    0.2kWh/Nm3
    Published value

  • High end of the published upgrading electricity, compared with the model value.

    0.3kWh/Nm3
    Published value

  • Design target of the CO2 polishing before the cold box, to avoid CO2 freezing out. The polishing is part of the upgrading block: no separate cost or power is added.

    Market range 50 ppm is the usual small-scale LNG spec; no independent range cited.

    50ppm
    Published value

  • Liquefaction electricity of reference case 1, a 610 kg/h containerised mixed-refrigerant unit.

    Market range Naerenergi slide 13: 0.66-0.85 kWh/kg across its range.

    0.82kWh/kg
    Published value

  • Liquefaction electricity of reference case 2, the best printed figure; also the yardstick of the efficiency penalty.

    Market range Nordsol prints 0.72 kWh/kg and Nord Gas PuregasMR below 0.65 (brief notes, not checked here).

    0.7kWh/kg
    Published value

  • Liquefaction electricity of reference case 3, a 200 kg/h micro system.

    0.9kWh/kg
    Published value

  • Liquefaction electricity of reference case 4, the smallest micro system (worst case).

    1kWh/kg
    Published value

  • Cost anchor of the liquefaction power law: budget price of a containerised 200 kg/h unit, no civil works, no storage, no loading.

    Market range Same slide: 1 MEUR at 40 kg/h, 2.2 MEUR at 120 kg/h; slide 16: 4.5-5.0 MEUR at 610 kg/h.

    2800000EUR
    Published value

  • Size of the liquefaction cost anchor.

    Market range Not applicable (reference size).

    200kg/h
    Published value

  • Independent budget point used to check the 0.6 law at 40 kg/h.

    Market range Budget estimate, no civil works.

    1000000EUR
    Published value

  • Size of the 40 kg/h check point; also the smallest size the cost law is anchored on.

    Market range Not applicable (reference size).

    40kg/h
    Published value

  • Independent budget point used to check the 0.6 law at 120 kg/h.

    Market range Budget estimate, no civil works.

    2200000EUR
    Published value

  • Size of the 120 kg/h check point.

    Market range Not applicable (reference size).

    120kg/h
    Published value

  • Low end of the 610 kg/h budget, used to check the 0.6 law at the largest anchored size.

    4500000EUR
    Published value

  • High end of the 610 kg/h budget.

    5000000EUR
    Published value

  • Size of the 610 kg/h check point; above it the liquefaction cost law is extrapolated.

    Market range Not applicable (reference size).

    610kg/h
    Published value

  • Service agreement of the liquefier, per kg of LNG produced (200 kg/h value, kept at all sizes).

    0.016EUR/kg
    Published value

  • Specific investment of the upgrading block at the DEA reference size (1,000 Nm3/h raw biogas); the grid-injection block of the data sheet is not included.

    Market range DEA uncertainty band 268,000-318,000 EUR/(MJ/s).

    302000EUR/(MJ/s)
    Published value

  • Reference size of the upgrading cost law, in MJ/s. The model's own input power at 1,000 Nm3/h and 60 % CH4 is 5.98 MJ/s, 1 % above.

    Market range Not applicable (reference size).

    5.92MJ/s
    Published value

  • Reference raw biogas flow of the whole-chain CAPEX law (the DEA anchor size).

    Market range Not applicable (reference size).

    1000Nm3/h
    Published value

  • Fixed O&M of the upgrading block, electricity excluded, proportional to its input power.

    Market range No independent range cited.

    7600EUR/(MJ/s)/year
    Published value

  • Exponent of the CAPEX power law for both blocks, as MMMCZCS applies it to its bio-LNG chains. Checked on the Naerenergi liquefaction budgets: 1.07 MEUR at 40 kg/h (budget 1.0), 2.06 at 120 kg/h (2.2), 5.47 at 610 kg/h (4.5-5.0, model 9-22 % above).

    Market range 0.6 rule is the textbook default; the Naerenergi points imply about 0.6-0.65 below 200 kg/h and lower above.

    0.6
    Published value

  • Floor of the clamp on the specific CAPEX. The model gives about 3,600-17,000 EUR/(Nm3/h) over the slider box, so the floor never binds.

    Market range Not applicable (guard).

    1000EUR/(Nm3/h)
    Numerical constant

  • Ceiling of the clamp on the specific CAPEX; never binds inside the slider box (checked at the corners).

    Market range Not applicable (guard).

    40000EUR/(Nm3/h)
    Numerical constant

  • Plant size at which Capra et al. print the liquefaction cost of the best option; used to re-run the model's liquefaction slice at the same size.

    Market range Plants 1-10 tCH4/day in the study.

    4.6t/d
    Published value

  • Specific liquefaction work of Capra's best option (0.85 kWh/kg), used in the cross-check.

    Market range Not applicable (single printed value).

    3061kJ/kg
    Published value

  • Published liquefaction-only cost (22.7 EUR/MWh LHV), compared with the model's liquefaction slice at the same size and specific energy.

    Market range Not applicable (single printed value).

    6.3EUR/GJ
    Published value

  • Low end of the whole-chain electricity per unit of raw biogas for bio-LNG plants with conventional upgrading. Baccioli's Sm3 (15 C) is about 5 % larger than a Nm3 (0 C): read as an indicative range.

    0.57kWh/Nm3
    Published value

  • High end of the same range (Sm3 basis, indicative).

    0.72kWh/Nm3
    Published value

  • Whole-chain electricity of an integrated cryogenic upgrading-liquefaction plant (Cryo Pur type), not modelled here, shown as a reference.

    Market range Not applicable (single printed value).

    1.45kWh/kg
    Published value

  • All-in bio-LNG cost of an integrated plant, LHV basis, including digestion, storage, civil works and LNG transfer. Wider scope than this calculator.

    120EUR/MWh
    Published value

  • High end of the same all-in figure.

    130EUR/MWh
    Published value

  • Low end of the biogas share of the all-in bio-LNG cost, compared with the model's share.

    50%
    Published value

  • High end of the same share.

    70%
    Published value

  • The discount rate input defaults to 7 % (real), the MMMCZCS value.

    Market range Slider 3-12 %.

    —
    Method and scope

  • The economic lifetime input defaults to 20 years, the MMMCZCS plant design life; it is also the physical service life exported to project mode.

    Market range Slider 15-25 years.

    —
    Method and scope

  • The availability input defaults to 95 %, the MMMCZCS value for every unit other than the digester (90 %).

    Market range Slider 80-98 %.

    —
    Method and scope

  • The electricity price input defaults to 55 EUR/MWh, the MMMCZCS assumption.

    Market range Slider 30-150 EUR/MWh.

    —
    Method and scope

  • The raw biogas price defaults to 80 EUR/MWh (LHV), the MMMCZCS production cost of biogas at about 500 Nm3/h; at 10,000 Nm3/h it is 50 EUR/MWh.

    Market range 50-80 EUR/MWh in the source; slider 50-120.

    —
    Method and scope

  • 60 % is the midpoint of the DEA 50-70 % range, not a printed value.

    Market range 50-70 %.

    —
    Method and scope

  • Raw biogas goes through membrane upgrading (H2S and water pre-treatment included), CO2 polishing to the liquefaction spec (CO2 50 ppm) and a containerised small-scale liquefier (mixed refrigerant or N2 expander class). Bio-LNG is taken as pure methane. Levelised cost: CAPEX times the capital recovery factor, plus O&M, liquefier service, electricity and raw biogas, over the yearly bio-LNG energy, as in MMMCZCS 2022.

    Market range No independent range cited.

    —
    Method and scope

  • LNG buffer storage, truck loading and civil works are not in the CAPEX: the Naerenergi budgets exclude them explicitly. Add them in project mode.

    Market range No independent range cited.

    —
    Method and scope

  • The DEA upgrading figure is a full investment; the Naerenergi liquefier is a budget price for the containerised unit without civil works. The chain is exported as ex-factory equipment so that project mode adds installation and indirect costs; this over-counts them on the upgrading part (about 29 % of the CAPEX at nominal).

    Market range No independent range cited.

    —
    Method and scope

  • Costs are not escalated: DEA figures are in the catalogue's price base, Naerenergi budgets in 2019 euros, MMMCZCS prices in 2022 euros. The page declares 2019. Read the costs as about 2019 money with a few percent of uncertainty from mixed years.

    Market range No independent range cited.

    —
    Method and scope

  • Integrated cryogenic upgrading (Cryo Pur type, about 1.45 kWh/kg in Baccioli 2018), heat recovery credits, CO2 liquefaction power and cost, and off-gas methane oxidation are not modelled.

    Market range No independent range cited.

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    Method and scope

  • MMMCZCS prints 120-130 EUR/MWh LHV all-in for a 580 Nm3/h biomethane plant, with biogas at 50-70 % of the cost, so upgrading plus liquefaction there is about 38-63 EUR/MWh LHV. This model gives about 19 EUR/MWh LHV without biogas at nominal: lower, because it leaves out storage, civil works, LNG transfer and grid items that MMMCZCS includes. For the same reason the raw biogas weighs about 80 % of the cost at nominal, above their 50-70 %.

    Market range No independent range cited.

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    Method and scope

  • At Capra's plant (4.6 t/d, 0.85 kWh/kg) the model's liquefaction slice is about 30 % below the published 6.3 EUR/GJ LHV (22.7 EUR/MWh) with the default prices and finance. The Naerenergi budget law is cheaper than Capra's costing; the gap is published as an output, not tuned away.

    Market range No independent range cited.

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    Method and scope

  • Whole-chain electricity is 0.57 kWh per Nm3 of raw biogas at nominal, at the low end of the 0.57-0.72 kWh/Sm3 Baccioli et al. give for bio-LNG plants with conventional upgrading (Sm3 basis, indicative).

    Market range No independent range cited.

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    Method and scope

  • The headline cost is per MWh HHV (PCS), as fuel contracts in France quote it; the LHV figure is about 11 % higher and is shown for comparison with MMMCZCS and Capra, which quote LHV.

    Market range No independent range cited.

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    Method and scope