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8 nationalities. Common link: ELECTRIFICATION
ANAEROBIC DIGESTION: CUTTING-EDGE DEVELOPMENTS CONTRIBUTING TO - - PowerPoint PPT Presentation
ANAEROBIC DIGESTION: CUTTING-EDGE DEVELOPMENTS CONTRIBUTING TO - - PowerPoint PPT Presentation
ANAEROBIC DIGESTION: CUTTING-EDGE DEVELOPMENTS CONTRIBUTING TO CARBON NEUTRAL PRODUCTION Korneel Rabaey 8 nationalities. Common link: ELECTRIFICATION 2 CO 2 TO PRODUCT WATER FIT FOR USE PLASTICS TO RESOURCE Coupling biomass digestion to
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WATER FIT FOR USE CO2 TO PRODUCT PLASTICS TO RESOURCE
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Coupling biomass digestion to centralized chemical production appears today
the only route
bringing profit to anaerobic digestion without subsidy in Europe It also enables considerable CO2 fixation
A chemistry-centric view on anaerobic digestion
Verbeeck et al. Energy & Environmental Science 2018
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Biogas valorization
- On-site combustion: engines, turbines or CHP units
- Upgrading and compression: vehicle fuel (CNG) or injected in the natural gas grid
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Primary biogas energy production (EU28) = 186 TWh (= 7% of total renewable energy production) Electricity
Heat (sold) Heat (consumed) Biomethane
“Losses”
31 % 16 % 42 % 4 % 7 %
Biogas production is mainly incentivized via the power and heat sector
Multiple references
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Average biogas production cost = 140 € ton-1
biogas
“Average” digester with an “average” organic feedstock
CAPEX 5000 €/Nm³ /h 20 years depreciation, 3% interest OPEX 7.5 % of the investment sum per year Feedstock cost
Free substrate (except for energy crops)
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A B
CASE 1 Combined Heat and Power (CHP) → break-even at an electricity price of 95 € MWhe
- 1 (or a subsidy of ± 60 € MWhe
- 1)
Italy 280 € MWh-1
…
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Biomethane production and injection increases overall biogas use
Decoupling in:
The natural gas grid provides large-scale and long-term biomethane storage Grid injection allows transmission of biomethane from the production sites to the end users Biomethane injection extends the valorization opportunities of biogas
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Biomethane: a fast growing sector in Europe
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Average biomethane production cost = 680 € ton-1
biomethane
2 – 5 times higher than the current average EU price for natural gas
0.49 ± 0.16 € Nm-3
biomethane
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A B
CASE 2 Grid injection of biomethane → break-even at a gas price of 45 € MWh-1
(or a subsidy of ±35 € MWh-1)
152 € MWh-1 The Netherlands
…
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- Profitability of investment in biogas/biomethane strongly depends on national supporting scheme
- Hard to compete with non-biomass renewable energy sources if it comes to energy production
- Numerous biogas plants struggle for their economic existence:
- higher prices for raw material,
- lower feed-in tariffs
- insufficient usage of waste heat
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Biogas: a rather expensive renewable energy/methane source
Biogas: 90 – 220 € MWhe
- 1
Solar PV projects: 50 – 90 € MWhe
- 1
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CH4 is not just a fuel, it is a chemical feedstock!
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Embed the carbon in chemicals (and fuels?), rather than burn
SDR = SuperDry Reforming DRM = Dry Reforming of Methane SRM = Steam Reforming of Methane
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Case C: ‘Super-dry’ reforming
Production of CO from biomethane
𝐷𝐼4 + 3𝐷𝑃2 → 4𝐷𝑃 + 2𝐼2𝑃
Case B: Dry (CO2) reforming
Production of syngas from biomethane
𝐷𝐼4 + 𝐷𝑃2 → 2𝐷𝑃 + 2𝐼2
Case A: Steam reforming
Production of H2 from biomethane
𝐷𝐼4 + 2𝐼2𝑃 → 4𝐼2 + 𝐷𝑃2 Buelens et al,. 2016, Science
CO2 use: 7.33 ton CO2 / ton CH4 CO production: 6.22 ton CO / ton CH4
Biomethane reforming allows CO2 utilization in a chemical looping process
Intensification of CO2 conversion
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Only the CO case generates profit
CO Syngas H2
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CASE 3 Super-dry reforming of biomethane
SDR DRM SRM
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Avoided CO2 emission taxes = 220 € ton-1
Industry can lower their emissions in a cost-effective way
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GHG: 4.45 Gton CO2, eq year-1 CO2: 2.94 Gton CO2 year-1
66 % 8 %
Industry: 290 Mton CO2 year-1 CO2 consumption for SDR
Feedstock quantification 2) CO2 1) bio-CH4
1.31 Mton bio-CH4year -1 (2016) Possible today: 10 Mton CO2 year-1 (or 4 % of industrial emissions) Possible 2030: 38 Mton bio-CH4year -1 212 Mton CO2 year-1
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GHG: 4.45 Gton CO2, eq year-1 CO2: 2.94 Gton CO2 year-1
66 % 8 %
Industry: 290 Mton CO2 year-1 Methanol production from CO
Feedstock quantification 2) CO2 1) bio-CH4
1.31 Mton bio-CH4year -1 (2016)
Today: 13 Mton methanol year-1 (or 13% of global methanol demand) By 2030: 377 Mton methanol year-1 (or 400%)
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Importance of CO in chemical synthesis
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Global substrate potential for biogas production = 28 times current production
Ethanol to Ethylene Methanol to Olefins (MTO)
57% of “industrial CO2” can be used as feedstock for chemicals
Fuels and raw chemicals Mt/year Mt C/year Mt CO/year Mt CO2/year Coal production (3)
7860 2360-6680 5500-15590 8650-24500
Oil production (3)
4400 3740 8800 13830
Natural gas production (3)
2870 2190 5060 7950 15130 8290-12610 19360-29450 30430-46280
Bulk chemicals Ethylene (1)a
154 132 308 484
Propylene (1)a
148 127 296 465
Olefins (via MTO process) (4)
11 9.4 22 35
Ethanol (5)
68 35.4 82.5 130
Methanol (1)a
98 37 86 134
Methanol (2)
55 20.6 48 75
Formaldehyde (6)
30 12 28 44
Acetic acid (7)
6.5 1.3 3 5 560 365 852 1337
Other chemicals Phosgene (8)
3 0.37 0.86 1.4
Acetaldehyde (9)
1 0.30 0.60 0.94
Polycarbonate (2)
4 0.14 0.34 0.53
Dimethylcarbonate (10)
0.4 0.053 0.13 0.20 8.4 0.86 1.9 3.07
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Take homes:
- Make the CO where CO2 is available and where
CO is needed
- Create added value for the methane within a
value chain
- Existing gas grid makes the connection between
producer and consumer. Make maximal use of the infrastructure! Avoid biomass transport! Three key innovation needs:
- Business models across ETS
- Cost effective technology for biogas upgrading
and compression at medium scale
- SDR further roll out
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