EP2536839A1 - Procédé et installation pour produire du biométhane comprimé (cbm) utilisé en tant que carburant à émission réduite de gaz à effet de serre - Google Patents

Procédé et installation pour produire du biométhane comprimé (cbm) utilisé en tant que carburant à émission réduite de gaz à effet de serre

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Publication number
EP2536839A1
EP2536839A1 EP11704934A EP11704934A EP2536839A1 EP 2536839 A1 EP2536839 A1 EP 2536839A1 EP 11704934 A EP11704934 A EP 11704934A EP 11704934 A EP11704934 A EP 11704934A EP 2536839 A1 EP2536839 A1 EP 2536839A1
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EP
European Patent Office
Prior art keywords
ghg
gas
biogas
regenerative
methane
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Withdrawn
Application number
EP11704934A
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German (de)
English (en)
Inventor
Michael Feldmann
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Meissner Jan A
Original Assignee
Meissner Jan A
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Filing date
Publication date
Application filed by Meissner Jan A filed Critical Meissner Jan A
Publication of EP2536839A1 publication Critical patent/EP2536839A1/fr
Withdrawn legal-status Critical Current

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    • C—CHEMISTRY; METALLURGY
    • C12—BIOCHEMISTRY; BEER; SPIRITS; WINE; VINEGAR; MICROBIOLOGY; ENZYMOLOGY; MUTATION OR GENETIC ENGINEERING
    • C12P—FERMENTATION OR ENZYME-USING PROCESSES TO SYNTHESISE A DESIRED CHEMICAL COMPOUND OR COMPOSITION OR TO SEPARATE OPTICAL ISOMERS FROM A RACEMIC MIXTURE
    • C12P5/00—Preparation of hydrocarbons or halogenated hydrocarbons
    • C12P5/02—Preparation of hydrocarbons or halogenated hydrocarbons acyclic
    • C12P5/023—Methane
    • C—CHEMISTRY; METALLURGY
    • C07—ORGANIC CHEMISTRY
    • C07C—ACYCLIC OR CARBOCYCLIC COMPOUNDS
    • C07C29/00—Preparation of compounds having hydroxy or O-metal groups bound to a carbon atom not belonging to a six-membered aromatic ring
    • C07C29/15—Preparation of compounds having hydroxy or O-metal groups bound to a carbon atom not belonging to a six-membered aromatic ring by reduction of oxides of carbon exclusively
    • C07C29/151—Preparation of compounds having hydroxy or O-metal groups bound to a carbon atom not belonging to a six-membered aromatic ring by reduction of oxides of carbon exclusively with hydrogen or hydrogen-containing gases
    • C07C29/1516—Multisteps
    • C07C29/1518—Multisteps one step being the formation of initial mixture of carbon oxides and hydrogen for synthesis
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
    • C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
    • C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
    • C10L3/08—Production of synthetic natural gas
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
    • C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
    • C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
    • C10L3/10—Working-up natural gas or synthetic natural gas
    • C10L3/101—Removal of contaminants
    • C10L3/102—Removal of contaminants of acid contaminants
    • C10L3/104—Carbon dioxide
    • C—CHEMISTRY; METALLURGY
    • C12—BIOCHEMISTRY; BEER; SPIRITS; WINE; VINEGAR; MICROBIOLOGY; ENZYMOLOGY; MUTATION OR GENETIC ENGINEERING
    • C12M—APPARATUS FOR ENZYMOLOGY OR MICROBIOLOGY; APPARATUS FOR CULTURING MICROORGANISMS FOR PRODUCING BIOMASS, FOR GROWING CELLS OR FOR OBTAINING FERMENTATION OR METABOLIC PRODUCTS, i.e. BIOREACTORS OR FERMENTERS
    • C12M21/00—Bioreactors or fermenters specially adapted for specific uses
    • C12M21/04—Bioreactors or fermenters specially adapted for specific uses for producing gas, e.g. biogas
    • C—CHEMISTRY; METALLURGY
    • C12—BIOCHEMISTRY; BEER; SPIRITS; WINE; VINEGAR; MICROBIOLOGY; ENZYMOLOGY; MUTATION OR GENETIC ENGINEERING
    • C12M—APPARATUS FOR ENZYMOLOGY OR MICROBIOLOGY; APPARATUS FOR CULTURING MICROORGANISMS FOR PRODUCING BIOMASS, FOR GROWING CELLS OR FOR OBTAINING FERMENTATION OR METABOLIC PRODUCTS, i.e. BIOREACTORS OR FERMENTERS
    • C12M21/00—Bioreactors or fermenters specially adapted for specific uses
    • C12M21/12—Bioreactors or fermenters specially adapted for specific uses for producing fuels or solvents
    • C—CHEMISTRY; METALLURGY
    • C12—BIOCHEMISTRY; BEER; SPIRITS; WINE; VINEGAR; MICROBIOLOGY; ENZYMOLOGY; MUTATION OR GENETIC ENGINEERING
    • C12M—APPARATUS FOR ENZYMOLOGY OR MICROBIOLOGY; APPARATUS FOR CULTURING MICROORGANISMS FOR PRODUCING BIOMASS, FOR GROWING CELLS OR FOR OBTAINING FERMENTATION OR METABOLIC PRODUCTS, i.e. BIOREACTORS OR FERMENTERS
    • C12M23/00—Constructional details, e.g. recesses, hinges
    • C12M23/58—Reaction vessels connected in series or in parallel
    • C—CHEMISTRY; METALLURGY
    • C12—BIOCHEMISTRY; BEER; SPIRITS; WINE; VINEGAR; MICROBIOLOGY; ENZYMOLOGY; MUTATION OR GENETIC ENGINEERING
    • C12M—APPARATUS FOR ENZYMOLOGY OR MICROBIOLOGY; APPARATUS FOR CULTURING MICROORGANISMS FOR PRODUCING BIOMASS, FOR GROWING CELLS OR FOR OBTAINING FERMENTATION OR METABOLIC PRODUCTS, i.e. BIOREACTORS OR FERMENTERS
    • C12M45/00—Means for pre-treatment of biological substances
    • C12M45/20—Heating; Cooling
    • C—CHEMISTRY; METALLURGY
    • C12—BIOCHEMISTRY; BEER; SPIRITS; WINE; VINEGAR; MICROBIOLOGY; ENZYMOLOGY; MUTATION OR GENETIC ENGINEERING
    • C12M—APPARATUS FOR ENZYMOLOGY OR MICROBIOLOGY; APPARATUS FOR CULTURING MICROORGANISMS FOR PRODUCING BIOMASS, FOR GROWING CELLS OR FOR OBTAINING FERMENTATION OR METABOLIC PRODUCTS, i.e. BIOREACTORS OR FERMENTERS
    • C12M47/00—Means for after-treatment of the produced biomass or of the fermentation or metabolic products, e.g. storage of biomass
    • C12M47/18—Gas cleaning, e.g. scrubbers; Separation of different gases
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E50/00—Technologies for the production of fuel of non-fossil origin
    • Y02E50/30—Fuel from waste, e.g. synthetic alcohol or diesel
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P20/00—Technologies relating to chemical industry
    • Y02P20/10—Process efficiency
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P20/00—Technologies relating to chemical industry
    • Y02P20/10—Process efficiency
    • Y02P20/129—Energy recovery, e.g. by cogeneration, H2recovery or pressure recovery turbines
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P20/00—Technologies relating to chemical industry
    • Y02P20/10—Process efficiency
    • Y02P20/133—Renewable energy sources, e.g. sunlight

Definitions

  • C0 2 carbon dioxide
  • CH methane
  • N 2 0 nitrous oxide
  • the various fluorocarbons, sulfur hexafluoride (SF 6 ), nitrogen trifluoride (NF 3 ) and other gases greenhouse gases (hereinafter also GHG) with a variety of Greenhouse gas effects are standardized and quantified using C0 2 equivalents. These are usually related to consumed energy units (eg gC0 2 -eq / kWh or gC0 2 -eq / MJ) or traveled distances (gC0 2 -eq / km).
  • the LCA consideration of, for example, gasoline also includes the emissions of (fossil) C0 2 , which are generated in the process chain by the crude oil tankers, by the pipelines, by the refineries, by the power plants that generate the electricity required in the production line. and be caused by the gas stations.
  • the greenhouse gas pollution results from the sum of the greenhouse gas emissions of all energies or all energy carriers that are involved in the cultivation of biomass, in their storage, in their transport, in their conversion to biogas, in the treatment of biogas to bio methane and in the compression and Ein - Supply of BioMethane in a natural gas network and its distribution are used.
  • corn Since corn not only requires a relatively large amount of mineral fertilizer, but also absorbs a relatively large amount of carbon from the soil, the most important fermentation substrate used for anaerobic bacterial fermentation (corn accounts for around 80% of the renewable resources used in biogas plants in Germany, approx. 60% of the total German biogas production comes from corn) in the sub-process "cultivation" is excessively burdened with the emission of greenhouse gases, in addition to the greenhouse gas effects resulting from the use of fossil diesel fuel in the various cultivation and harvesting processes (pre-treatment of the field, sowing Fertilization, treatment with fungicides and pesticides, harvest, etc.).
  • the processed bio methane is fed into a natural gas grid. Natural gas networks are under considerable pressure. Therefore, the bio methane must be brought to the respective pressure level during the feed-in with energy-intensive compressors. Usually electricity from the regional electricity mix is used here. In Germany this is
  • bio methane fed into the natural gas network is transported regionally during distribution.
  • Compressors are also used, which either use fossil natural gas or electricity from the regional electricity mix as energy.
  • the activities taking place in this sub-process lead to greenhouse gas emissions. This additionally pollutes the LCA greenhouse gas balance of the product "BioMethan”.
  • bio-methane produced from corn over the whole production process is 140 gC0 2 -equivalent / kWh-methane to 234 gC-0, depending on the design of the production route 2 equivalents / kWh-methane loaded.
  • conventionally produced BioMethane achieves a reduction of 23% to 54%, a greenhouse gas freedom or a so-called C0 2 neutrality energy content not more than 0 g of (fossil) C0 2 equivalents are emitted per kWh, but is far from given.
  • BioMethan is not per se C0 2 -free, but pollutes the environment to a considerable extent.
  • the invention is therefore based on the object to eliminate the lack of GHG burden of conventional bio methane and to create a process and a usable plant for the conversion of biomass, which have as an energy source whose greenhouse gas pollution is significantly lower than that of conventionally produced bio-methane, and which can be used as greenhouse-gas-reduced fuels, preferably as greenhouse-gas-free and particularly preferably as greenhouse gas-negative fuels in traffic.
  • greenhouse gas reduced in this disclosure means, depending on the context, a reduction in fossil greenhouse gas (GHG) emissions to levels below either the LCA value of conventional bio methane (140-234 g C0 2 -equivante / kWh) or below the LCA value of natural gas (233 - 245 gC0 2 -equivalent / kWh) or below the LCA value of gasoline and diesel (302 gC0 2 -equivalent / kWh).
  • GSG fossil greenhouse gas
  • the GHG balance is optimized by additionally carrying out a GHG-oriented control of the energy input in each of the process steps, i. the greenhouse gas load is minimized in each case. This is done both on the fiction, contemporary selection of each used in the process steps energy sources and energy as well as on the design of the individual process steps themselves.
  • sub-methods are preferably used in the individual process steps, which burden the GHG balance less than other possible sub-methods.
  • greenhouse gas-free straw greenhouse gas-free agricultural residues such as straw-containing straw and mixtures of straw and liquid manure and greenhouse gas-poor organic waste are used, ie substrates that do not need to be specially grown and therefore in the process step " Substrate cultivation / harvest "until collection are not contaminated or to a very limited extent with greenhouse gases.
  • the design of the overall process using the optional process steps reveals that the resulting product "BioMethane” or "CBM” (Compressed BioMethane) becomes greenhouse gas-negative, the shares of low-greenhouse NawaRo or possibly also of greenhouse gas-rich NawaRo at Frischmasse input until the LCA greenhouse gas balance of BioMethan or CBM has barely changed from negative to positive. The generated energy sources thus remain at least greenhouse gas free.
  • tractors and / or trucks are used, which are powered by greenhouse gas-free or greenhouse gas-negative bio-methane or a mixture of fossil diesel, greenhouse gas-free or greenhouse gas-negative bio-methane and fossil natural gas or with a corresponding natural gas equivalent, so that the greenhouse gas pollution of the process step " Transport "even with a blend of bio methane and natural gas with fossil diesel to a mixed fuel very low precipitates and the GHG load preferably due to a greenhouse gas neutrality of the fuel mixture even goes back to zero
  • substrate acceptance and intermediate storage of the substrates in the biogas plant is as in Care should be taken to ensure substrate storage that no emissions of methane or ammonia or nitrous oxide occur, and that rotting processes are prevented as far as possible, with the result that this sub-process also remains GHG-free.
  • the pretreatment of the straw and the straw-containing feedstocks takes place in such a way that the energy expenditure used in this process step is smaller than the additional energy yield attributable to the pretreatment.
  • the use of greenhouse gas-free energy ensures that this sub-process also remains GHG-free.
  • GHG-negative bio-methane or a corresponding natural gas equivalent produced by this method is used so that the greenhouse gas emissions load of diesel fuel also used is compensated and the overall GHG balance of this process step remains neutral.
  • greenhouse gas-free energies are also used in a modified fermentation process or in a modified biogas plant, preferably greenhouse-gas-free electricity produced by the conversion plant itself and greenhouse gas-free heat generated by it itself.
  • the "conversion" sub-process also does not contribute, or hardly does so, to any greenhouse gas emissions that contribute to a poor greenhouse gas balance of the energy sources produced (biogas, bio methane, alternative fuel, bioethanol, if applicable) and the generated energies (electricity, heat).
  • the generated biogas and the biogas supplied from external sources are distributed among the 3 utilization strands and sub-processes "power generation”, “biogas scrubbing / C0 2 separation” including the subsequent “C0 2 recuperation” and “C0 2 reforming ".
  • biogasau preparation includes the deposition of C0 2 according to one of the known methods (inter alia, pressure swing absorption, non-pressurized A- minissesche, cryogenic cooling technology).
  • the C0 2 is geologically stored (sequestered), but it can also be used in a further sub-process "Substitution of fossil CO?" used as a material substitute for fossil C0 2 or in the subprocess "CO ⁇ reforming" to a regenerative energy source, preferably according to the known Sabatier process to synthetic methane (CH 4 ) or according to the known methods (steam reforming, Bertau / Piserold / Singliar-V) to synthetic methanol (CH 3 OH).
  • the biogas produced according to the method and / or the biogas recuperated from external sources and / or the recuperated regenerative CO 2 can be reformed into bio-methane and / or bio-methanol in the optional "CO? -Reforming" sub-process as described above, for example for methanol synthesis
  • the steam reforming (sub-) processes of steam reforming have been in use for decades in other applications, but the required amounts of electricity and heat are covered by regenerative or at least low-GHG sources of energy for the methanation of C0 2
  • the well-known Sabatier process can be used, whereby the hydrogen required for this purpose is to be generated electrolytically by means of GHG-free electricity, so that the hydrogen thus produced is not burdened with GHG emissions (hitherto hydrogen is mostly made from fossil, GHG-contaminated Natural gas or produced as a waste product of the chemical industry).
  • the C0 2 reformer When the C0 2 reformer releases synthetic methane, it is physically added to biogas from biogas scrubbing; in the GHG balance, it replaces fossil natural gas and, if natural gas replaces diesel fuel or gasoline, with diesel and gasoline. In the case of the production of bio-methanol, this energy source is supplied separately for use, preferably as a greenhouse gas reduced fuel component. BioMethanol also replaces fossil fuels, resulting in GHG credits attributed to BioMethan.
  • the bio methane produced in accordance with the process is preferably fed into an existing natural gas grid in the feed-in subsystem.
  • "Since gas networks are usually under considerable gas pressure, it is necessary to compress the bio methane using energy-intensive compressors, which become more efficient with increasing size , in the upstream sub-process "Compression". It is therefore not least beneficial for the GHG balance if the compression quantities and thus also the feed-in quantities are as large as possible.
  • THG-free electricity is also used as the current in this process step, so that the fed-in bio-methane remains at least THG-free, but preferably GHG-negative.
  • the gases "BioMethan” and “Regenerative C0 2 " produced in accordance with the process can be delivered in the liquid state.
  • the energy used for this purpose originates from regenerative sources which are preferably low in greenhouse gases and particularly preferably produced free of greenhouse gases and in particular by the conversion plant itself GHG balance for liquefied gases GHG-free or GHG-negative
  • the gasses "BioMethan” and “Regeneratives C0 2 " in the gaseous state are required, then it is necessary to fill and deliver them in pressure tanks energy-intensive compressors in the sub-process "bottling".
  • greenhouse gas-reduced electricity is used, preferably low-GHG electricity, particularly preferably greenhouse gas-free electricity and in particular greenhouse gas-negative electricity.
  • the intermediate storage and filling of the liquid energy carriers takes place. It may be necessary to cool the filled tanks. This cooling also takes place with low-GHG or THG-free electricity or with dry ice produced from regenerative C0 2 according to the process, so that the energy sources generated remain GHG-free or THG-negative.
  • the sequestration of regenerative C0 2 has the greatest effect on the GHG balances of the process or on the energy products obtained by the process. This is not a computational assignment, the C0 2 is rather physically stored in deep geological formations.
  • the effective CO reduction (final removal of the regenerative C0 2 from the C0 2 cycle) is attributed to the main product of the process, the bio-methane, which is the main reason for the GHG-freedom or GHG negativity of the produced BioMethans.
  • Another positive effect of the GHG effect is that the residual energy contained in the fermentation residues is harnessed in an optional sub-process "fuel production.”
  • alternative fuel pellets prepared from fermentation substitute fossil greenhouse gas-releasing fuel oil or fossil greenhouse gas-releasing natural gas or even fossil fuel Greenhouse gas-releasing coal: These avoided greenhouse gas emissions are also attributed to BioMethan, which further improves its GHG balance sheet.
  • the BioMethane is mixed with natural gas, which can be physically mixed before the BioMethane feeds into the natural gas grid by extracting and decompressing the natural gas from the grid and using the pressureless BioMethane. mixed and then compressed together with this again and returned to the network. It is more elegant and advantageous if the BioMethan and / or the SynMethan is first brought to the pressure level of the network into which it is to be fed, if it is mixed with the natural gas taken from the gas network but still under pressure, and when finally a return to the natural gas network takes place.
  • the "BioMethan” and “Regenerative C0 2 " gases are distributed either via gas pipelines or, as in the case of BioMethanol, with mobile tanks.
  • the distribution of the BioMethan is preferably carried out using trucks with or without greenhouse gas-free or greenhouse gas-negative BioMethane a mixture of fossil diesel, greenhouse gas-free or greenhouse gas-negative bio-methane and fossil natural gas or a corresponding natural gas equivalent are driven, so that the greenhouse gas pollution of the process step "distribution” even when mixing the bio methane and natural gas with fossil diesel to a mixed fuel very low and the GHG load may even decrease to zero due to greenhouse gas neutrality of the fuel mixture.
  • the overall objective of the invention is the production of greenhouse-gas-reduced energy carriers, preferably the production of greenhouse-gas-free energy carriers and, particularly preferably, the production of greenhouse gas-negative (! Energy carriers. While fossil
  • the energy carriers generated by the method disclosed here should significantly undercut the GHG load of 120 gC0 2 -equivalent kWh and, ideally, reach -468 gC0 2 -equivalent / kWh.
  • the greenhouse gas reduction of the bio methane produced in accordance with the innovative process should go so far that the energy source "bio methane / natural gas mixture” has a GHG emission of ⁇ 120 gC0 2 -equivalent / kWh and thus be used as a greenhouse gas-reduced energy source
  • Another goal is the use of energy sources as fuel in traffic, preferably in a mixture of bio methane and natural gas as greenhouse gas-poor fuel with a GHG load of ⁇ 50 gC0 2 -equivalent / kWh, particularly preferably as greenhouse gas-free fuel and in particular as a greenhouse gas-negative fuel.
  • THG negative bio methane can be generated by the method disclosed herein.
  • the THG-negative bio methane can then be mixed with fossil and thus greenhouse gas-loaded natural gas (CNG) with a corrugated load of about 233 - 245 gC0 2 -equivalent / kWhcNG Mixed gas any GHG load between -468 gC0 2 -
  • CNG greenhouse gas-loaded natural gas
  • GHG reduction effects can be achieved. These can reach 35% or 50% or 60% or 80% or even 100% if the mixing ratio is appropriate.
  • CNG GHG-contaminated natural gas
  • the particular advantage of mixing GHG-negative bio methane with fossil, GHG-contaminated natural gas (CNG) is that the GHG reduction effect of natural gas is added to the GHG reduction effect of BioMethane.
  • FIGS. 1 to 18 show exemplary embodiments of the method according to the invention, namely:
  • Figure 1 is a schematic block diagram of the essential process steps for the production of biogas from GHG-rich NawaRo, the deposition of C0 2 and the use of GHG-reduced bioMethane as GHG-reduced or THG-free energy source
  • Figure 2 is a schematic block diagram of a development of in 1, comprising a feed of greenhouse-gas-reduced bio-methane into a natural gas grid, an outfeed of an energy equivalent and its use as a THG-reduced or THG-free fuel
  • FIG. 3 shows a schematic block diagram of a development of the method described in FIG. 2 with low-GHG NawaRo as the fermentation substrate
  • Figure 4 is a schematic block diagram of a development of the method described in Figure 3 with THG-free or low-GHG organic waste as a fermentation substrate
  • FIG. 5 shows a schematic block diagram of a development of the method described in FIG. 4 with straw and straw-containing starting materials as fermentation substrates
  • FIG. 6 shows a schematic block diagram of a development of the method described in FIG. 5 comprising a pretreatment of the fermentation substrates straw and straw-containing feedstocks
  • Figure 7 is a schematic block diagram of a development of the method described in Figure 6 comprising the optional use of low-GHG and / or GHG-rich renewable resources as additional fermentation substrates
  • FIG. 8 shows a schematic block diagram of a development of the preceding method variants, comprising a selection from a wide range of starting materials and the use of regenerative and greenhouse gas-poor energies in the various method steps
  • FIG. 9 shows a schematic block diagram of a development of the method described in FIG. 8 comprising a net-external mixing of the produced bio-methane with natural gas
  • FIG. 10 a schematic block diagram of a development of the method described in FIG. 9 comprising an optional reforming of the CO 2 contained in the THG-reduced biogas to THG -reduced SynMethan and / or to GHG-reduced SynMethanol
  • FIG. 11 shows a schematic block diagram of a development of the method described in FIG. 10, comprising an optional reforming of separated regenerative CO 2 to give THG-reduced bio-methane and / or to THG-reduced bio-methanol
  • FIG. 12 shows a schematic block diagram of a development of all the methods described above, comprising a substitution of fossil CO 2 by deposited regenerative CO 2
  • FIG. 13 shows a schematic block diagram of a development of all the methods described above, including an optional generation of electricity from GHG-reduced biogas
  • Figure 14 is a schematic block diagram of one embodiment of all the methods described above including optional liquefaction of greenhouse gas reduced bio methane or mixed gas consisting of greenhouse gas reduced biomethane and natural gas
  • Figure 15 is a schematic block diagram of a development of the method described in Figure 8 comprising an optional utilization of the digestate as a mineral fertilizer substitute
  • FIG. 16 shows a schematic block diagram of a development of the method described in FIG. 15, comprising an optional extraction of plant nutrients from the fermentation residues and their optional utilization in a fertilizer production
  • FIG. 17 shows a schematic block diagram of a further development of the method described in FIG. 16, comprising an optional preparation of the solid fermentation residues for alternative fuel
  • FIG. 18 shows a schematic block diagram of a further development of the method described in FIG. 17 comprising an optional recuperation of the fuel ash and its utilization as fertilizer component.
  • FIGS. 1 to 18 show processes as a rectangle and substances or products as a rectangle with cut corners.
  • plants or devices are shown as a rectangle and fabrics or products as a rectangle with cut corners.
  • Figures 19 to 39 show embodiments of the system according to the invention, namely:
  • Figure 19 is a schematic block diagram of the essential components of a biogas plant for the production of greenhouse gas reduced bio methane and regenerative C0 2 and the use of greenhouse gas reduced BioMethans as a greenhouse gas reduced or greenhouse gas free gas fuel
  • FIG. 20 shows a schematic block diagram of a development of the system described in FIG. 19, comprising the use of a fermentation substrate mixture improved with regard to the GHG balance
  • FIG. 21 shows a schematic block diagram of a further development of the plant described in FIG. 20, comprising the use of straw and straw-containing feedstocks as fermentation substrates.
  • FIG. 22 shows a schematic block diagram of a development of the plant described in FIG. 21, comprising a housed acceptance area and an enclosed intermediate storage facility
  • FIG. 23 shows a schematic block diagram of a development of the plant described in FIG. 22, comprising plants for the pretreatment of straw and straw-containing starting materials
  • FIG. 24 shows a schematic block diagram of a development of the plant described in FIG. 23, comprising the additional use of organic waste as a fermentation substrate
  • FIG. 25 shows a schematic block diagram of a further development of the system described in FIG. 24, comprising the additional use of low-GHG and GHG-rich renewable raw materials as a fermentation substrate
  • FIG. 26 shows a schematic block diagram of a development of the system described in FIG. 25, comprising the additional or alternative use of regenerative CO 2 as substitute for fossil CO 2
  • FIG. 27 shows a schematic block diagram of a further development of the system described in FIG. 26, comprising the additional use of digestate as a substitute for mineral fertilizer.
  • FIG. 28 shows a schematic block diagram of a development of the system described in FIG. 27, comprising a secondary fermenter
  • FIG. 29 shows a schematic block diagram of a further development of the plant described in FIG. 28, comprising a compressor for compressing the generated greenhouse-reduced bio-methane (Compressed BioMethane CBM) and at least one feed-in point for the feed of this bio-methane into a natural gas or a bio-methane network
  • a compressor for compressing the generated greenhouse-reduced bio-methane Compressed BioMethane CBM
  • FIG. 30 shows a schematic block diagram of a development of the system described in FIG. 29, comprising at least one exit point for the outfeed of BioMethane or BioMethan substitute or BioMethane / natural gas mixtures or corresponding energy equivalents from a natural gas network.
  • FIG. 31 shows a schematic block diagram of a development the plant described in Figure 30, comprising facilities for converting the produced greenhouse gas reduced biogas to GHG-reduced electricity
  • FIG. 32 shows a schematic block diagram of a development of the plant described in FIG. 31, comprising a plant for reforming biogas into bio-methane or bio-methanol
  • FIG. 33 shows a schematic block diagram of a development of the plant described in FIG. 32, comprising a connection from the C0 2 capture and recrystallization plant to the C0 2 reformation plant for introducing recuperated regenerative C0 2 into the C0 2 reformation plant
  • FIG. 34 shows a schematic block diagram of a further development of the system described in FIG. 33, comprising a device for the net-external mixing of greenhouse-reduced bio-methane with natural gas, for compressing the mixed gas and for feeding the compressed mixed gas into a natural gas network
  • FIG. 35 shows a schematic block diagram of a development of the plant described in FIG. 34, comprising a plant for the liquefaction of greenhouse-gas-reduced bio-methane or a gas mixture consisting of greenhouse-gas-reduced bio-methane and natural gas
  • FIG. 36 shows a schematic block diagram of a development of the plant described in FIG. 35, comprising a plant for extracting plant nutrients from the resulting fermentation residues
  • FIG. 37 shows a schematic block diagram of a development of the plant described in FIG. 36, comprising a fertilizer treatment plant for processing the extracted organic nutrients into fertilizers and fertilizer components
  • Figure 38 is a schematic block diagram of a development of the system described in Figure 37, comprising systems for processing the solid part of digestate to alternative fuel
  • Figure 39 is a schematic block diagram of a development of the system described in Figure 38, comprising a boiler with devices for recuperation of the digestate
  • FIG. 1 shows the simplest embodiment of the method. It reproduces the common basic principle of a biogas plant, but with the additions a) separation of regenerative C0 2j b) recuperation of the separated regenerative C0 2 , c) geological disposal (sequestering) of the separated and recuperated regenerative C0 2 and d) use of the GHG-reduced BioMethans as a greenhouse gas-reduced energy source.
  • Subvariants of this embodiment variant may consist in the fact that the bio-methane is used as a greenhouse gas-reduced fuel or (not shown) as a greenhouse gas-free or greenhouse gas-negative energy carrier or as a greenhouse gas-free or greenhouse gas-negative fuel.
  • the respective fuel is preferably used in traffic (see claims 2 and 5).
  • the conventionally generated (GHG-loaded) biogas and possibly supplied from external sources biogas in the process steps "biogas scrubbing / CO ⁇ -Abborgung” and "recuperation of regenerative CO?" processed into bio methane.
  • the biogas is "washed" in a gas treatment plant, ie the biogas with about 39 - 47% contained C0 2 and other gases (sulfur, ammonia, nitrogen, oxygen, which together contain about 5% in the biogas) are separated This is done with conventional methods (inter alia with a pressure swing process) or with the (sub-) process of pressureless amine scrubbing, but preferably with a previously unused refrigeration process (cryo-technology) .
  • the deposited regenerative CO 2 is not as usual but released for further use (recuperated) and possibly stored or fed into a gas line (see address 1)
  • the uses of the recuperated C0 2 include the geological disposal (sequestering), its reforming into synthetic methane ( SynMethan) or synthetic methanol (SynMethanol) and the material substitution fossil C0 2 (see claim 1).
  • GHG greenhouse gas
  • the C0 2 can be stored geologically only at selected locations, it usually has to be transported from the deposition apparatus to the sequestering location. This is done cooled in liquid tanks or in gaseous form in pressure tanks or in solid form as dry ice or in gaseous form via a C0 2 line . Apart from transport by means of a dedicated gas line, trucks which use GHG-free fuel (see claim 1) are preferably used as the means of transport.
  • the GHG balance of the resulting bio methane drastically improves: the biogas produced conventionally from the conventional feedstock "GHG-rich NawaRo" is initially burdened with GHG emissions (when using maize according to the latest studies) with 140-234 GC0 2 -.
  • the method illustrated in FIG. 2 is an advantageous development of the embodiment variant of the method described in FIG.
  • the process is improved by distributing the THG-reduced or THG-free BioMethan or CBM after an appropriate feed via a natural gas or bio methane network. This modification reduces the distribution costs and lowers the energy input.
  • Process step preferably uses THG-reduced, preferably THG-free, stream (see claim 1). Compressing converts the pressureless or moderately pressurized BioMethane into so-called “compressed bio-methane” (also referred to below as CBM).
  • the CBM is fed into the intended section of a natural gas or bio-methane network in accordance with the "feed-in” process step (see claim 2.)
  • the feed is also preferably carried out using GHG-reduced, preferably preferably THG-free, electricity (cf. Claim 1). Since there are strong volume effects when feeding BioMethane into natural gas grids, it is advantageous if the volumes fed in have a minimum size (see claim 7).
  • the physical or virtual / statistical transport of the bio methane fed into a natural gas or bio methane network takes place to the consumer, where the fed bio methane mixes with the natural gas in the network (see claim 2)
  • the fed bio methane mixes with the natural gas in the network
  • they can also be mixed in such a way that natural gas is taken from the natural gas network and mixed with the CBM outside the natural gas network (see the embodiment of FIG.
  • the most elegant and advantageous is when the mixing is done only statistically / virtually, for example, such that pure BioMethan or a mixture of bio methane, propane and / or butane is fed into a natural gas network and this mixture is mixed in the natural gas network with natural gas.
  • the gas finally taken by the consumer from the natural gas network has a certain amount of THG-negative bio-methane relative to a certain amount of energy (energy or natural gas equivalent) and therefore corresponding excess amounts of (mixed) gas be taken from the natural gas network.
  • the possible withdrawal quantities result from the GHG target load, i. the higher the permitted GHG pollution of the withdrawal gas, the greater the possible withdrawal quantity (see claim 2).
  • gas fed out is compared with the gas fed in via energy or natural gas equivalents or at the same energy content of the gases over standard quantities (Nm). If the quantities of energy fed out and fed in correspond to the outgassing quantities, they can be referred to as "pure CBM.” If the amounts of energy expelled are greater than the amounts of energy fed in, then the gas expelled is by definition a CBM / CNG mixture GHG possible negativity of the CBM may still have a GHG load of 0 GC02 eq / kWh i SC H gas with the removed CBM / CNG mixture.
  • an energy-equivalent quantity plus an additional quantity of natural gas can be taken at any exit point of the natural gas network, which can be extracted by virtual / statistical clearing with exactly the same (negative) Physically, the extracted gas is not identical with the injected CBM, but other than the natural gas consumers connected to the designated exit point use it to a greater or lesser extent without knowing it Ultimately, it does not matter for the global climate, where the GHG saving takes place.
  • the end consumers emit correspondingly lower amounts of long-term, fossil C0 2. Stoichiometrically, the resulting C0 2 amount remains unchanged Only a certain proportion of the "short" C0 2 cycle is from the long-term fossil C0 2 cycle.
  • the amount of energy expelled corresponds exactly to the amount of CBM fed in, then it is possible to accurately attribute the GHG effects of the fed CBM to an outgassed gas quantity. If the exit quantity measured in Nm is greater than the CBM feed amount, then a dilution of the GHG effect takes place, and this dilution can be continued until the desired GHG value is reached. For example, if the GHG "load" of the injected CBM is -468 gC0 2 -
  • Equivalent / kWhc BM and a TGH-free mixed gas is to be fed, can at a dedicated exit point in total per 1 kWh of fed CBM approx. 2.98 kWh of gas (1 kWhc of BM with a GHG load of -468 gC0 2 - eq / kWhc BM and 1.98 kWhcNG with a GHG load of +236 gC0 2 -eq / kWhcNG gives 2.98 kWh Ausspeisegas with a THG-load of 0 GC0 2 eq / kWh a usspeisegas) - The common or average GHG load is then at 0 GC0 2 equivalents / kWliAuss eisegas- Ausspeisegas This can inter alia as GHG reduced or GHG free fuel can be used (see claim 5).
  • the dilution may also go so far as to achieve a GHG value between 0 and 235 gC0 2 -eq / kWh of feed gas or between 0 and 301 gC0 2 -eq / kWh feed gas.
  • Ausspeisegase then apply in the first case as compared. Natural gas (CNG) GHG reduced and in the second case as compared to. Gasoline GHG reduced.
  • CBM is considered to be Conventionally produced from maize produced bio methane GHG-reduced, if its GHG value (according to most recent studies approx. 140 - 234 gC0 2 -Equivalent / kWhBioMethan) is fallen below. If the GHG load of the exhaust gas at 0 gC0 is 2 equivalents / kWh "cBM" > then the discharged "CBM" can be designated as greenhouse gas-free fuel and used as such.
  • the discharged "CBM” can be designated as greenhouse gas-negative fuel and used as such. If the GHG load of the fed-out "CBM” is above 0 gC0 2 -equivalents / kWh "cB", but still below 236 gC0 2 -equivalent / kWh "cBM”> then the fed-out "CBM” can be compared to. Natural gas is a greenhouse gas-reduced energy source.
  • CBM / CNG blended feeds: if their GHG load is between 0 and 235 gCO2 equivalents / kWti of mixed gas, the mixed gas is GHG-reduced, the GHG load is exactly 0 gC0 2- equivalent / kWh mixed gas, then it is THG-free mixed gas, if it is below it, then the mixed gas is GHG negative. It is advantageous to use the discharged "CBM” and the “CBM” / CNG mixtures as greenhouse gas-reduced or in greenhouse gas-free fuels, preferably in traffic (see claim 5).
  • the method illustrated in FIG. 3 is an advantageous development of the embodiment variant of the method described in FIG.
  • the GHG balance of the process is improved by using to a greater extent also low-GHG NawaRo as fermentation substrate in the process step "substrate selection.”
  • GHG arms NawaRo are, for example, landscaped property, growth of extensively cultivated land, grass and miscanthus. Maize and fertilizer-intensive substrates such as green cereal crop cut are not low greenhouse gas NawaRo, they are therefore used in this embodiment only in second choice as a fermentation substrate.
  • the GHG effect is all the more positive, the higher the proportion of low-GHG NawaRo in the fresh mass.
  • the biogas is already GHG-reduced, because in particular low-GG substrates are used (those introduced in the variants of FIGS. 1 and 2) Process changes only affect the GHG value of the BioMethane, not the GHG value of the biogas produced in the manufacturing process).
  • the process step "substrate selection” is configured in FIG. 5 such that exclusively greenhouse-free straw and greenhouse gas-free agricultural residues (including farmyard manure) were selected as the fermentation substrates (cf claim 3) harvest "almost completely. Straw must be e.g. only pressed into bales and collected, with solid manure eliminates the pressing, he only has to be collected. With regard to the greenhouse gas effect, this selection is the conventional feedstocks (meaning the maize, cereal whole plant cut, cereal grains, grass silage, beets) are given a first advantage, that is to say, until including the process step "substrate cultivation", a zero or almost zero GHG load is used ,
  • substrate storage care is taken in accordance with the method disclosed here that the stored feed materials do not exhale methane or nitrous oxide (cf claim 1.)
  • the various mastic are taken immediately after their removal from the barn and into a BGA-internal , enclosed and with a vacuum bleeding tion provided temporary storage. Also rotting processes are prevented if possible, because the oxidation processes taking place are connected with the production of C0 2 .
  • the straw is stored dry, so that no (aerobic) rotting processes can take place and thus no C0 2 enters the atmosphere.
  • substrate transport are used in the transport of biomass from the place of the attack to biogas plant according to the invention innovative tractors and trucks that are operated with greenhouse gas free, preferably with greenhouse gas-negative bio methane or with a mixture of fossil diesel, greenhouse gas-free or greenhouse gas-negative bio-methane and fossil Natural gas or with a corresponding natural gas or energy equivalent (cf claim 1) .
  • the greenhouse gas pollution of the process step “transport” is therefore very low, even if the bio methane and natural gas are mixed with fossil diesel, preferably the GHG pollution of the fuel used even back to zero.
  • it has a positive effect that the means of transport are covered during transport of the biomass, except when transporting straw.
  • substrate acceptance and intermediate substrate storage care is taken to avoid emissions of methane or nitrous oxide, which is possible, for example, if the substrate assumption in the biogas plant is in a completely enclosed acceptance area
  • the buffer is also completely enclosed, and both areas are connected to a negative pressure vent, which in turn vented into the combustion air flow of CHP.Recovery processes are as far as possible prevented, so that as far as possible no C0 2 is released.
  • FIG. 6 shows a positive development of the method described in FIG.
  • it is gas-yielding to subject these fermentation substrates to a pretreatment. This is done in the optional process step "pretreatment" (see claim 4) .
  • pretreatment see claim 4 .
  • a higher gas yield per tonne of input means that ultimately more fossil energy sources are being replaced and thus an increased amount of greenhouse gases is avoided.
  • Pretreatments include, in particular, the mechanical pretreatment of the milling, the chemical pretreatment of the soaking in acidic solutions, the thermochemical pretreatment with saturated steam, the thermomechanical pretreatment by means of steam explosion, the thermochemical pretreatment by means of thermal pressure hydrolysis and the chemical pretreatment by means of mixing with solid manure or manure and the addition of exo-enzymes in question (see claim 4).
  • the pretreatment of the straw and the straw-containing feedstocks takes place in such a way that the energy expenditure used in this process step is smaller than the additional energy yield attributable to the pretreatment.
  • low-THG, particularly preferably THG-free, energy or energy carriers are used in this process step.
  • Procedural steps should show that the resulting product "bio methane" is greenhouse gas negative, and the target is a GHG-free CBM, then the proportions of cultivated biomass with a lower GHG load than corn or possibly also greenhouse gas loaded corn at the fresh mass input until the greenhouse gas balance of the CBM just now does not change from a negative emission value (GHG load ⁇ 0 gC0 2 -equivalent / kWh) to a positive emission value (GHG load> 0 gC0 2 -equivalent / kWh). If the other fermentation substrates are not available in sufficient quantities, it may be advantageous if the proportion of NawaRo is as high as possible, because they are always available for purchase.
  • FIG. 8 shows the possibility of using any substance from the range of straw, straw-containing feedstocks, organic waste, low-GHG NawaRo and THG-rich NawaRo as fermentation substrate in the process. It should be expressly pointed out that the process described in this embodiment can in principle be carried out with other fermentation substrates than the listed starting materials and without the process steps "compression” and / or "feed”.
  • substrate transport are used in the transport of biomass from the place of the attack to biogas plant according to the invention.
  • innovative tractors and trucks that are operated with greenhouse gas free, preferably with greenhouse gas-negative bio methane or with a mixture of fossil diesel, greenhouse gas-free or greenhouse gas-negative bio-methane and fossil Natural gas or equivalent natural gas equivalents (see claim 1)
  • the various masticates are loaded immediately after their removal from the barn and brought into a BGA-internal, enclosed and provided with a vacuum venting intermediate storage
  • the greenhouse gas pollution of the process step "substrate transport” falls This means that even when mixing the (GHG-negative) bio methane and the natural gas with fossil diesel very low, preferably the GHG load of the fuel used even goes back to zero. Another positive factor is that the
  • Means of transport are covered during transport of the biomass except when transporting straw.
  • substrate acceptance / intermediate storage care is taken to ensure that no methane or nitrous oxide evaporates, for example if the substrate assumption in the biogas plant is in a completely enclosed acceptance area
  • the buffer is also completely enclosed, and both areas are connected to a negative pressure vent, which in turn vented into the combustion air flow of CHPs.Restation processes are as far as possible prevented, so that as far as possible no C0 2 is released.
  • Greenhouse gases is contaminated. Therefore it should also be subsumed here that in all procedural Steps in which electricity or heat are used, they come from renewable sources or have particularly low, preferably no GHG emissions (see claim 1).
  • the goal of GHG reduction is also achieved if there is no optimization with regard to greenhouse gas effects at each individual process step or in each individual sub-process.
  • the use of GHG-free or GHG-reduced energies in one or more process steps can also be dispensed with.
  • the effect resulting from the sequestering of the regenerative C0 2 alone is sufficient with almost complete CO 2 deposition, recuperation and sequestering to negate the THG exposure of the CBM (which results in a positive THG effect overall).
  • the design element of the C0 2 sequestration can - but not necessarily - be supplemented by other elements with the effect of a GHG reduction or avoidance or be replaced by other design elements.
  • the GHG-reduced BioMethane 1 originating from the process steps “biogas scrubbing / CO 2 precipitation” and “CO 2 recuperation” is already present in the process step “non-grating mixing” Feed into the natural gas network mixed with natural gas (cf claim 2).
  • This off-grid mixing can take place at different pressure levels: a) without pressure, ie at the level of ambient air, b) at the pressure level of the natural gas extracted from a natural gas network, and c) at any pressure level between a) and b).
  • the pre-compressed BioMethane is physically mixed with the CNG extracted from the natural gas network and not decompressed. After mixing outside the network, the precompressed mixed gas is compressed a little further so that it can be fed into the natural gas network against the pressure.
  • the energies used in this process step should originate from regenerative sources, which are preferably low in greenhouse gas and particularly preferably free from greenhouse gas.
  • This process step of the net-external mixing of greenhouse-gas-reduced bio-methane and CNG can be incorporated as an independent process step in any other embodiment of the process, for example in a process in which the BioMethan is not generated by a C0 2 -Abborgung from the biogas, but by a reforming of the C0 2 component contained in the biogas (see below). In this respect, it is also immaterial whether or not further method steps or modules are added to the embodiments listed above.
  • the GHG-reduced biogas from the anaerobic bacterial fermentation is supplemented or alternative to the process steps "biogas scrubbing / C0 2 separation” and “C0 2 -recuperation” in a process step "C0 2 - reforming".
  • the GHG-reduced BioMethan 2 (SynMethan) is either mixed with or replaced by the BioMethane 1 originating from the "Biogas scrubbing / C0 2 separation" process step, ie the BioMethan 2 is mixed with either CNG instead of the BioMethan 1 in the latter case and fed into the natural gas grid or pure or mixed with propane and / or butane highly compressed to slightly above the pressure level of a natural gas network and then fed into this natural gas network.
  • the use is the same as described in FIG.
  • C0 2 reforming The amounts of electricity and heat required in process step "C0 2 reforming" are preferably covered by regenerative or at least low greenhouse gas energy sources (see claim 1) .
  • Co 2 reforming also has volume effects (scale effects), so that it is advantageous is when the volume flow of the supplied C0 2 is as large as possible (see claim 7.)
  • volume effects scale effects
  • biogas production and C0 2 reforming plants are located farther apart - as is the case, for example, with biogas parks, or if several smaller biogas plants supply a larger separation unit with biogas - transport of the biogas is required Advantage, because it is less expensive technically and economically, if this transport over a biogas line he follows (see claim 7).
  • any electricity suitable for electrolysis is reduced to ⁇ 100 gC0 2 equivalents / kWhei greenhouse gas.
  • electricity is used from wind or hydroelectric power or from geothermal energy or from solar plants or electricity obtained by means of photovoltaics.
  • electricity which was generated according to the method disclosed here (see Figure 13 f.) And atomic and fusion current (see claim 1). Under certain circumstances, it may make sense to accept GHG emissions, for example if the electricity required for the electrolysis is particularly favorable.
  • regenerative C0 2 are used in the industry when the other two options are not available.
  • the simplest is the substitution of dry ice, which can be produced by Kxyo-V experienced without special effort already in this process step as a finished product.
  • FIG. 13 shows a method step which can be integrated into all variants of embodiment: partial or complete conversion of the greenhouse gas reduced biogas produced by anaerobic bacterial fermentation.
  • the electricity generated is also reduced by GHG. If the volumes of electricity produced from the biogas meet the needs of the process, the process becomes energy self-sufficient. As long as the C0 2 capture and C0 2 reforming options are unavailable, it is beneficial to exhale all biogas. Since BioMethan, which was produced according to the method disclosed here, is usually more valuable than effluent biogas - especially when used as a fuel - it may be advantageous to minimize the biogas content that goes into the process step "power generation" in that the Bio gasver flow is limited to its own use (see claim 5).
  • the bio-methane produced according to the process can also be delivered in a liquid state In liquid form, the energy density is much greater, which reduces the transport costs.
  • the gases are cooled in this process step (see claim 1.)
  • the energies used for this purpose should originate from renewable sources, preferably are low greenhouse gas and particularly preferably greenhouse gas free (cf claim 1.)
  • the cooling can also be carried out according to the process of regenerative C0 2 produced dry ice, possibly via heat exchangers.
  • CNG can be added to the greenhouse gas-reduced bio methane before or during liquefaction.
  • Per kWh BioMethan can be mixed between 0,1 kWh and 20 kWh CNG (see above).
  • the liquefied greenhouse gas-reduced bio-methane or the liquefied bio-methane / CNG mixture is preferably used as a THG-reduced or THG-free fuel.
  • the process step "liquefaction" can be integrated including the provision of any CNG necessary in each embodiment of the method and thus all the above variants.
  • the user of the process can decide as follows: a) which feedstocks are used in which fractions, b) whether or not they should be pretreated, c) with which proportion the GHG-reduced biogas goes into which recycle line, i ) with which share the recuperated C0 2 in which recovery strand is, e) whether the greenhouse gas reduced BioMethan generated is to be liquefied or not, f) if the gaseous greenhouse gas reduced BioMethan is mixed in the natural gas network or outside the network with natural gas and g) if the "CBM "is to be used as GHG-free or as GHG-reduced fuel, ie in what ratio it is mixed with CNG.
  • FIG. 15 shows an alternative embodiment of the method described in FIG. 8, the fermentation residues occurring during anaerobic bacterial fermentation being used as a mineral fertilizer substitute (cf claim 1).
  • the substitution of mineral fertilizer avoids additional GHG emissions associated with the production and application of the mineral fertilizer. This avoidance of GHG emissions is attributed to the main product of the process, the CBM. Both the GHG balance sheet of the process and the GHG balance sheet of CBM improve considerably.
  • the process step "nutrient extraction” and the process step “fertilizer production” are added to the process described in FIG.
  • the vegetable nutrients contained in the fermentation residues are extracted. This is done by first mechanically dehydrating the fermentation residues, preferably with at least one
  • the liquid phase is dehydrated a second time, preferably with at least one decanter.
  • the liquid phase of the decanter is first subjected to an ultrafiltration before a pre-filtration and only then ultrafiltration.
  • the permeate from the ultrafiltration is subjected either to a precipitation or to a reverse osmosis.
  • organic nutrients are extracted, mainly nitrates, potassium and phosphates, possibly also magnesium and various salts.
  • This GHG effect becomes even more positive if energies from regenerative sources are used in one or both process steps, which are preferably low in greenhouse gases and particularly preferably free of greenhouse gas (cf. claim 1).
  • the fuel pellets replace fossil fuel (heating oil, coal or natural gas), thus avoiding large amounts of GHG emissions.
  • This GHG prevention is ascribed to the process or the main product GHG-reduced bio methane or CBM, which further improves the GHG balance sheets. It is advantageous for each embodiment in terms of energy, to integrate the fuel production in the process - which is quite possible and should be protected hereby.
  • the fuel pellets continue to replace fossil fuel (heating oil, coal or natural gas). It is advantageous for each embodiment variant to integrate the recuperation of the fermentation residue and its utilization in the respective process variant - e.g. This is quite possible and should be protected as well as the integration of the two process steps "fuel production” and "ash recovery” in any other variant.
  • the GHG balances of the process or of the CBM can still be improved by a whole series of process modifications.
  • the process step “conversion” according to the invention only low-GHG or greenhouse gas-free energies can be used, preferably self-generated greenhouse gas-free electricity and self-generated greenhouse gas-free heat (cf claim 1.)
  • the process step “conversion” thus also contributes little or no greenhouse gas effects a poor greenhouse gas balance of the biogas produced, the other energy sources generated (bio-methanol, alternative fuel) and the energy generated (electricity, heat).
  • the GHG balance of the product BioMethan not or hardly burden with greenhouse gases (see claim 1).
  • the method was selected according to the invention, which has the highest conversion rates and the lowest equipment costs, ie the best combination of substrate efficiency and system efficiency and thus the best overall efficiency. This is the anaerobic bacterial fermentation (see claim 1).
  • substrate selection In order to avoid the initially high greenhouse gas pollution of cultivated biomass, in a first process step "substrate selection" fermentation substrates are selected which do not have this greenhouse gas pollution or only to a small extent: greenhouse-gas-free residues, including solid manure (see claim 3), greenhouse gas-poor organic waste ( see claim 3) and renewable raw materials (NawaRo), which are preferably low greenhouse gas in the process step "cultivation” (see claim 3).
  • the "internal transport" step can be a significant source of greenhouse gas pollution GHG-negative bio-methane or a corresponding natural gas equivalent is used as fuel for the wheeled or telescopic loader, so that the greenhouse gas emissions of the likewise used natural gas and diesel fuels are compensated (see claim 1).
  • Stationary conveyors are electrically operated. For this purpose, use is made of THG-reduced, preferably THG-free, current (cf claim 1).
  • biogas distribution By integrating the process step "biogas distribution" into the overall process, a flexible control or regulation of the respective biogas components is possible, so that the generation of the various energy sources can be adapted to the changing conditions.Technically, the biogas flow is controlled by simple valves in the corresponding gas lines.
  • the gases "BioMethan” and “Regeneratives C0 2 " are required in a gaseous state. This is the case with BioMethan, for example, when there is no natural gas grid. Since there is (still) no public C0 2 network, it is necessary to then fill and deliver these two gases in pressure tanks. This happens with power-intensive compressors in the Again, greenhouse-gas-reduced electricity is used, preferably low-greenhouse gas electricity, particularly preferably greenhouse-gas-free electricity and, in particular, greenhouse gas-negative electricity.
  • the distribution of the gases "BioMethan” and “Regeneratives C0 2 " takes place either via gas pipelines or, as in the case of BioMethanol, with mobile tanks If trucks are to be used for the distribution of the gases, they should be treated with greenhouse gas-free or greenhouse gas-negative BioMethane or with a mixture of fossil diesel, greenhouse-gas-free or greenhouse-gas-negative bio methane and fossil natural gas or with a corresponding natural gas equivalent, the greenhouse gas load of the process step "distribution” is then very low, even if bio-methane and natural gas are mixed with fossil diesel to form a mixed fuel If necessary, the greenhouse gas emissions of the fuel mixture are even reduced to almost zero due to the greenhouse gas neutrality of the fuel mixture.
  • volume effects (scale effects or economies of scale) occur in several process steps. It is therefore in each embodiment of advantage to build the largest possible biogas plants and operate (see claim 7).
  • GHG-reduced preferably low-GHG, particularly preferably GHG-free and especially GHG-negative BioMethan can be produced whose GHG reduction effect compared.
  • Natural gas (CNG) is at least 100 gC0 2 -equivalent / kWh B i 0 methane or 180 gC0 2 -equivalent / kWh-methane or 236 gC0 2 -equivalent / kWh-3-methane and 336 gC0 2 -equivalent / kWh-3-methane, respectively.
  • the preferably GHG-negative BioMethan can then be mixed with fossil and thus greenhouse gas-loaded natural gas (CNG, THG load well-to-wheel at 236 gC0 2 -equivalent / kWhcNG) that the resulting mixed gas any GHG Load between -468 gC0 2 -equivalent / kWhMisch as and +236 gC0 2 -equivalent / kWliMischgas exhibits.
  • CNG greenhouse gas-loaded natural gas
  • THG load well-to-wheel at 236 gC0 2 -equivalent / kWhcNG any GHG Load between -468 gC0 2 -equivalent / kWhMisch as and +236 gC0 2 -equivalent / kWliMischgas exhibits.
  • CNG greenhouse gas-loaded natural gas
  • THG load well-to-wheel at 236 gC0 2 -equivalent / kWhcNG any GHG Load between
  • FIG. 19 shows the simplest embodiment variant of the system according to the invention. It represents the common modules of a biogas plant, but with an additional conditioning module for separating regenerative C0 2 from the produced biogas, an additional conditioning module for the recuperation of the deposited regenerative C0 2 (in the figures 19 ff., The conditioning module "C0 2 "Recuperation” is not shown separately, but together with the plant module "Biogas Laundry / C0 2 - Separation"), an additional, remote geological repository for sequestering the recovered and recuperated renewable C0 2 and using the greenhouse gas reduced BioMethans produced in the plant as GHG-reduced or THG-free gas fuel (see claim 8).
  • GHG-contaminated biogas will at least produce GHG-reduced bio methane (g EU-RED calculated LCA value will be ⁇ 137 g C0 2 -equivalent / kWh B joMethaji), Preferably GHG free BioMethan (according to EU-RED LCA calculated value at 0 g C0 2 - equivalent / kWhßioMethan) (and especially preferably GHG negative BioMethan according to EU-RED calculated LCA-value ⁇ 0 g C0 2 equivalents / kWh B i 0 methane)
  • the GHG negativity of BioMethane makes it possible to mix the GHG negative bio methane with natural gas, without the GHG balance of the mixed gas exceeding the zero line, ie 0 gC0 2 -equivalent / kWl mixing gas. Therefore, especially the system arrangements according to the invention for mixing greenhouse gas-reduced bio-methane with (fossil) natural gas are to be protected, in particular plant arrangements for mixing greenhouse-gas-negative bio-methane with (fossil) natural gas (see claim 9).
  • FIGS. 29 et seq The corresponding embodiment variants are described in FIGS. 29 et seq. It is expressly understood, however, that the additional plant modules described in these figures may be added to any embodiment of the plant.
  • Subvariants of the embodiment of the system described in Figure 19 may consist in that the BioMethan is not reduced greenhouse gas, but even greenhouse gas or greenhouse gas negative, or that the bio methane is not used as fuel, but quite generally as a greenhouse gas reduced or greenhouse gas free or greenhouse gas negative energy source or in that the bio-methane is used as fuel in traffic (see claim 10).
  • the C0 2 can be stored geologically only at selected locations, it usually has to be transported from the deposition and recuperation device to the sequestering location. This is done cooled in liquid tanks or gaseous in pressure tanks or in solid form as dry ice or gaseous via a C0 2 line . Except for transport by means of dedicated gas line, trucks and / or ships which use GHG-free fuel are preferably used as means of transport.
  • FIG. 20 shows as a block diagram that the GHG load or the GHG balance of the BioMethane produced in the plant can be further improved solely by selecting the starting materials according to the invention.
  • the conventional, GHG-rich fermentation substrates corn, cereal crop, beets and cereal grains are not used, but GHG poor substrates such.
  • Landscaped land, the cultivation of extensively cultivated land, grass and miscanthus reduces the GHG burden on the biogas produced. Conventional biogas thus becomes GHG-reduced biogas.
  • the GHG reduction is greater, the higher the proportion of low-GHG renewable raw material in the total fresh mass input.
  • the selection of the starting materials comprises in the embodiment of Figure 21 exclusively greenhouse gas-free straw and greenhouse gas-free agricultural residues (including straw-containing farmyard manure).
  • These feedstocks eliminate the GHG-intensive substrate cultivation and the likewise GHG-intensive substrate harvest.
  • straw only needs to be pressed into bales and collected, and the straw-laden solid manure eliminates the need to squeeze it just has to be collected.
  • Regarding the greenhouse gas pollution of the biogas is compared with this selection. All NawaRo (greenhouse gas-rich and greenhouse gas-poor NawaRo) achieved a first lead, that is, up to and including the substrate harvest is operated with a zero or zero GHG load. As mentioned above, there are even GHG credits for the use of ammonia-containing manure.
  • GHG emission during substrate storage and substrate transport may even be negatively affected by GHG.
  • innovative tractors and trucks are used, which are operated with greenhouse gas free, preferably with greenhouse gas negative BioMethan or with a mixture of fossil diesel, greenhouse gas or greenhouse gas negative BioMethan and fossil natural gas or with a corresponding natural gas equivalent (see claim 1).
  • the greenhouse gas load on the transport is therefore very low, even if bioMethane and natural gas are mixed with fossil diesel.
  • the GHG load of the fuel used for the biomass transport even goes back to zero.
  • it has a positive effect that the means of transport are covered during transport of the biomass, except when transporting straw.
  • the block diagram of FIG. 22 depicts an advantageous development of the system described in FIG.
  • the biogas plant will be given a facility called "substrate acceptance / storage", which will be equipped with facilities that capture and neutralize emissions of methane or nitrous oxide, for example if the substrate assumption in the biogas plant is completely enclosed Acceptance area takes place, the buffer is also completely housed, and both areas are connected to a vacuum venting, which in turn vented into the combustion air flow of CHP ..
  • Figure 23 shows a positive development of the plant described in Figure 22.
  • it is gas-yielding to subject these fermentation substrates to a pretreatment, which is done in optional plants for the pretreatment or digestion of straw Gas yield per tonne of input means that ultimately more fossil fuels will be replaced and thus an increased amount of greenhouse gases will be avoided.
  • plants for the pretreatment of straw and / or straw-containing feedstocks are in particular mills (hammer mills, ball mills) into consideration, for soaking the straw or the straw-containing feedstocks in acidic solutions tank and container for the pre-treatment of the straw with a shredding of the straw Saturated steam
  • Pre-treatment plants using steam explosion and pretreatment plants using thermal pressure hydrolysis and pretreatment of the straw by mixing with solid manure or areas with liquid manure or silo facilities and spraying or distribution facilities for the addition of exo-enzymes.
  • the plants for the pretreatment of the straw and the straw-containing feedstocks are selected and configured such that the final energy input used in these plants is less than the additional final energy yield from the feedstocks due to the use of these additional plants.
  • FIG. 24 shows a system with which the GHG balance can be determined by the use of organic waste (the organic portion of household waste and commercial waste) as a fermentation substrate is kept low (see claim 13).
  • organic waste the organic portion of household waste and commercial waste
  • FIG. 24 shows a system with which the GHG balance can be determined by the use of organic waste (the organic portion of household waste and commercial waste) as a fermentation substrate is kept low (see claim 13).
  • the use of organic waste in the biogas plant is advantageous if in the catchment area of the biogas plant not enough straw and straw-containing feed materials are to be found. Since organic waste is hardly contaminated with GHG emissions, an improvement in the GHG value of the biogas is achieved solely by switching from NawaRo to organic waste. Together with the C0 2 already shown in FIGS. 19 to 23 -
  • FIG. 25 shows the possibility of using any substance from the range of straw, straw-containing feedstocks, organic waste, low-GHG renewable raw materials and THG-rich NawaRo as a fermentation substrate in the plant. It should be expressly pointed out that the plant described in this embodiment can in principle also be operated with organic fermentation substrates other than the listed starting materials and without the plant modules "acceptance area and intermediate storage” and / or "pretreatment plants”.
  • innovative tractors and trucks are used that are operated with greenhouse-gas-free, preferably greenhouse-gas-negative bio methane or with a mixture of fossil diesel, greenhouse gas-free or greenhouse gas-negative bio methane and fossil natural gas or with a corresponding natural gas equivalent (cf claim 1).
  • the various mats are loaded immediately after their removal from the barn and brought into a BGA-internal, enclosed and provided with a vacuum vent interim storage (s.u.).
  • the greenhouse gas load caused by the means of transport is therefore very low, even if biomethane and natural gas are mixed with fossil diesel, and the GHG burden of the fuel used is preferably even zero.
  • Another positive factor is that the means of transport are covered when transporting the biomass except when transporting straw.
  • regenerative C0 2 are used in the industry when the alternative of C0 2 sequestering is not available.
  • the simplest method is the substitution of dry ice with dry ice, which can be produced by Cryo technique without any further additional effort after the C0 2 -reecuperation.
  • FIG. 27 shows an advantageous embodiment of the system configuration described in FIG. 26, wherein the fermentation residues accumulating in the at least one fermenter are used as a mineral fertilizer substitute.
  • the substitution of mineral fertilizer avoids additional GHG emissions associated with the production and application of the mineral fertilizer. This avoidance of GHG emissions is attributed to the main product of the plant, BioMethan, whose GHG balance sheet is significantly improved.
  • FIG. 28 shows an advantageous development of the system configuration listed in FIG.
  • the fermentation residues from the at least one fermenter are fed into at least one additional secondary fermenter, whereby additional greenhouse gas reduced biogas is produced.
  • Additional biogas from the same input amount means an increase in substrate efficiency.
  • To produce the same amount of GHG-reduced gas fuel fewer feedstocks are required at a higher substrate efficiency. This is for the operator of the facilities of considerable advantage.
  • the system module "secondary fermenter" can also be integrated into all other system configurations, that is also into the system configurations described in Figures 19 to 26. These combinations should also be protected.
  • the system configuration shown in FIG. 29 is an advantageous further development of the embodiment variant of the system described in FIG.
  • the plant will be improved by distributing the GHG-reduced BioMethane after it has been fed in via a natural gas grid.
  • the resulting from the gas scrubbing GHG reduced bio methane is compressed by means of at least one compressor module to a slightly higher pressure level, as in the natural gas network section prevails, in which it is to be fed.
  • Compressors are usually power-intensive. However, the relative, related to a certain amount of gas power consumption decreases with increasing size of the compressor module. It is therefore not least of advantage for the GHG balance if the feed-in quantity is as large as possible (cf claim 1 1).
  • As a current as possible GHG-reduced, preferably GHG-free stream is used in this system module (see claim 1). Compression turns the pressureless or moderately pressurized BioMethan into so-called "Compressed BioMethane" (also referred to below as CBM).
  • the CBM will be fed into the designated section of a natural gas or bio-methane network.
  • a natural gas or bio-methane network In the physical or virtual-statistical transport of the fed and compared.
  • Conventional BioMethane greenhouse gas reduced CBM to the consumer, the fed BioMethan mixes with the natural gas in the network, it can not physically be separated from the natural gas. This mixing is intentional, because it is not intended to market pure CBM, but just a mixture of CBM and natural gas (CNG) or a corresponding natural gas equivalent.
  • CNG natural gas
  • the additional compressor module can be integrated in any of the above embodiments of the system. This optional integration should also be protected.
  • the system configuration shown in the block diagram in FIG. 30 is an advantageous further development of the embodiment variant of the system described in FIG. Due to the impossible physical separation of CBM and CNG, gas fed in is compared with the gas fed in via energy equivalents or with the same energy content of the gases over standard quantities (Nm 3 ). When the quantities of energy fed out and fed in are equal, the outgassing quantities can be termed "pure CBM.” If the amounts of energy expelled are greater than the amounts of energy supplied, then the outgassed gas is a "CBM" / CNG mixture.
  • an energy-equivalent quantity of natural gas can be produced at any exit point of the network.
  • CBM BioMethane
  • Equivalent / kWhc BM and a TGH-free mixed gas is to be fed, can be fed at a dedicated exit point a total of 2.98 kWh (1 kWhc BM with a GHG load of -468 gC0 2 -eq / kWh CB M and 1, 98 kWhc NG with a GHG load of +236 gC0 2 -eq / kWhcNG) -
  • the common or average GHG load is then 0 gC0 2 -equivalent / kWh AuS feedgas-
  • This exit gas can be used as GHG or GHG -free fuel can be used.
  • the dilution can also go so far that a GHG value 0-235 GC0 2 eq / is achieved kWliAus feed gas or 0-301 GC0 2 eq / kWh A u S feed gas.
  • These exit gases then apply in the first case as compared to.
  • BioMethan is considered to be Conventional bio-methane GHG-reduced if its GHG value (bio methane produced from corn according to latest studies approx. 140 - 234 gC0 2 -equivalent / kWh-methane) is undercut.
  • the discharged CBM can be designated and used as a non-GHG fuel and if it is above 0 gC0 for the discharged CBM 2 -equivalent / kWhcBM, but still below 236 gC0 2 -equivalent / kWhcBM, then the fed-out "CBM” can be referred to as greenhouse gas reduced energy carrier or fuel compared to natural gas
  • the mixed gas is Natural gas GHG reduced; if the GHG load is 0 gC0 2 equivalents / kWl mixed gas, then it is GHG-free mixed gas, if it is lower, then the mixed gas is GHG negative.
  • the GHG reduction compared to gasoline is 262 gC0 2 equivalents / kWh or approximately 87%, at A GHG load of the "CBM" / CNG mixed gas of 0 gC0 2 equivalents / kWh M ischgas 302 gC0 2 - equivalents / kWh mixed gas or approx. 100%.
  • FIG. 31 shows a system configuration that can be integrated into all variants of the embodiment: the partial or complete generation of power of the greenhouse gas-reduced biogas produced in the biogas plant.
  • the electricity generated and the heat generated are also reduced by GHG.
  • the system becomes energy self-sufficient.
  • the options of C0 2 capture and the C0 2 -Reformierung are not available, it is advantageous to flow the entire biogas (see claim 11).
  • BioMethan which was produced in one of the embodiments described here, is usually more valuable than effluent biogas, especially as a fuel, it may be advantageous to minimize the proportion of biogas that goes into the power plants. This happens u.a. in that the biogas power generation is limited to its own use.
  • GHG values are as it were given to the self-generated electricity and the self-generated heat when used internally by the system, whereby the system modules in which this GHG-reduced or GHG-free electricity and the GHG-reduced or GHG-free Heat are used and relieved of their GHG values.
  • the GHG-reduced biogas from the at least one fermenter and the at least one post-fermenter is supplemented or optionally added to the plant modules "biogas scrubbing / CO 2 precipitation”. and "C0 2 -reecuperation" as well
  • the SynMethanol is preferably used as a GHG-reduced fuel component.
  • the at least GHG-reduced SynMethan is either mixed with or replaced by the BioMethane originating from the "biogas scrubbing / C0 2 capture" and "C0 2 recuperation” plant modules, ie in the latter case, the SynMethane changes to bio methane instead
  • the quantities of electricity and heat required in the "C0 2 Reformation" system module are preferably covered by regenerative or at least low-GHG energy sources (see claim 1) .
  • Co 2 reforming also has volume effects (scale effects), which makes it an advantage is, if the volume flow of the supplied gases is as large as possible (see claim 1 1).)
  • volume effects scale effects
  • the implementation of each of the listed measures to reduce GHG emissions is advantageous or mandatory.
  • this hydrogen should come from renewable sources or not be contaminated with GHG emissions, which prohibits the use of fossil sources and / or energy sources
  • the current used for this purpose should preferably originate from regenerative sources (cf claim 1) .
  • each current is suitable for electrolysis, which in accordance with LCA ⁇ 100 gC0 2 - equivalent / kWh e is greenhouse gas reduction i
  • electricity from wind or water power or geothermal or solar panels or by means of photovoltaic recovered stream or produced from biomass stream is used in question here is also current that was generated by the presently disclosed system configuration.. (see Figures 31 et seq.) And atomic and fusion current (see claim 1.) Under certain circumstances it may sense mac to accept GHG emissions, eg if the electricity required for the electrolysis is particularly favorable.
  • FIG. 33 based on the plant configuration described in FIG. 32, an advantageous embodiment variant is described in which the recuperated C0 2 is not completely guided into a geological repository, but rather into the CO 2 reforming plant.
  • the recuperated C0 2 is not completely guided into a geological repository, but rather into the CO 2 reforming plant.
  • the GHG balance and / or the manufacturing costs and / or the economic contribution margin it may be advantageous if the largest possible amount of the deposited and recuperated C0 2 is passed into the C0 2 reforming, where from the regenerative C0 2 a regenerative energy source is produced that substitutes fossil fuels (see above).
  • the GHG-reduced bio-methane originating from the plant modules "biogas scrubbing / CO 2 precipitation” and "C0 2 recuperation” is led into a plant module for off-grid mixing, where it already exists the feed into the natural gas network with natural gas, preferably with compressed natural gas (CNG) is mixed.
  • This off-grid mixing can take place at different pressure levels: a) without pressure, ie at the level of ambient air, b) at the pressure level of the natural gas extracted from a natural gas network, and c) at any pressure level between a) and b).
  • the pre-compressed BioMethane is physically mixed with the CNG extracted from the natural gas network and not decompressed. After mixing outside the network, the precompressed mixed gas is compressed a little further so that it can be fed into the natural gas network against the pressure.
  • the energy used in this plant module should come from renewable sources, which are preferably low greenhouse gas and particularly preferably greenhouse gas free.
  • This system module for the net external mixing of greenhouse-gas-reduced bio-methane and CNG can also be installed as an independent system module in any other system combination listed so far, for example in a system in which the BioMethan is not isolated from the biogas in a C0 2 -Abborgevorraum, but the C0 2 - proportion of biogas is reformed in a reforming plant to BioMethan, so that the entire biogas is BioMethan. In this regard, it is also immaterial whether the installation variants listed above are added or not.
  • the advantageous embodiment of Figure 35 corresponds to the system described in Figure 34, but also includes the system module "liquefaction.”
  • the BioMethan generated in the system can also be dispensed in a liquid state when using this system module It makes sense to use GHG-reduced bio methane as a fuel in regions without a gas grid connection.
  • the energy density in liquid form is considerably higher, which reduces the transport effort.
  • the gases in the system module are cooled (cf.
  • the energy carriers or energy used for this purpose are to originate from regenerative sources, which are preferably low in greenhouse gases and particularly preferably free from greenhouse gases. Cooling can also be carried out with dry ice produced in the plant from regenerative C0 2 , possibly via heat exchangers.
  • CNG may be added to the GHG-reduced BioMethan before or during liquefaction.
  • Per kWh BioMethan between 0,1 kWh and 20 kWh CNG can be added (see above).
  • the liquefied greenhouse-gas-reduced bio-methane or the liquefied bio-methane / CNG mixture or their natural gas equivalent is preferably supplied to the market for use as a THG-reduced or THG-free fuel (cf claim 16).
  • the "Condensing" system module including the provision of any necessary CNG, can be integrated into every variant of the system and thus also in all the above versions.
  • the operator of such a plant can decide the following: a) which ingredients are used in which proportions, b) whether they should be pretreated or not, c) with what proportion of the GHG-reduced biogas is fed into which utilization strand, d ) is the proportion with which the recuperated out C0 2 in which recovery strand, e) whether the greenhouse gas reduced BioMethan generated is to be liquefied or not, f) if the gaseous BioMethan greenhouse gas reduced in G) whether the "CBM" is to be used as GHG-free or GHG-reduced fuel, ie in what proportion it is mixed with CNG.
  • the protection should not only include the complete plant configuration but also changes and modifications to the disclosed plant configuration and its variants.
  • variants of execution are also to be protected which lack individual system modules, e.g.
  • the plant module "nutrient extraction” is added to the plant configuration described in Figure 35.
  • the plant module "nets outside mixing” or the plant module “pretreatment” or the plant module “compressor plant.”
  • the plant nutrients contained in the liquid phase of the digestate are extracted in several stages. This is done by first mixing the fermentation residues with water in a post-fermenter and then mechanically dehydrating them in a screw press or a comparable device (other suitable presses, extruders).
  • the liquid phase is dehydrated a second time, preferably with at least one decanter.
  • the liquid phase of the decanter is first passed through a pre-filter before being fed into the ultrafiltration plant and only then into the ultrafiltration plant.
  • the permeate of the ultrafiltration plant is either fed into a precipitation plant or into a reverse osmosis plant.
  • the organic nutrients are extracted, essentially nitrates, potassium and phosphates, possibly also magnesium and various salts.
  • the organic nutrients substitute mineral fertilizer or mineral fertilizer components, thereby avoiding the GHG emissions resulting from the production and application of the mineral fertilizer.
  • the positive effect on GHG emissions is attributed to the plant's main product, BioMethan or CBM.
  • the GHG effect is even more positive if energies from renewable sources are used in this plant module, which are preferably low in greenhouse gases and particularly preferably free of greenhouse gases.
  • the plant module "Nutrient Extraction" can be integrated into any of the previously described variants as well as any other variant.
  • FIG. 37 shows an advantageous embodiment variant of the system configuration described in FIG.
  • the extracted organic nutrients are additionally fed into a fertilizer plant, where fertilizers and / or fertilizer components are produced from them. These substitute mineral fertilizers, thereby avoiding the GHG emissions resulting from the production and application of the mineral fertilizer.
  • the positive effect on GHG emissions is attributed to the plant's main product, BioMethan or CBM.
  • the GHG effect is even more positive if, in the production of fertilizers, energies from regenerative sources are used, which are preferably low in greenhouse gases and particularly preferably free of greenhouse gases.
  • the plant module "fertilizer plant” can be integrated into any of the variants already described, as well as into any other embodiment variant.
  • the variant of FIG. 38 corresponds to that of FIG. 37, but advantageously supplemented by the plant module "fuel production”.
  • the solid phase from the mechanical dehydrogenation 1 (which is made with a screw press or similar device) is no longer used untreated as Mineral Domaingersubstitut, but in a dryer (belt or drum dryer) guided, dried there, then in a crushing device (hammer or Ball mill), crushed there and finally fed into a pellet press to be pelletized there to fermentation residue pellets.
  • this plant module Preferably in this plant module low-GHG and particularly preferably propellant gas-free energies and energy sources are used, which reduces the C0 2 -Fußabuba the plant or the BioMethans considerably.
  • the digestate pellets replace fossil fuel (heating oil, coal or natural gas), thus avoiding large amounts of GHG emissions.
  • This GHG prevention is ascribed to the process or the main product GHG-reduced bio methane or CBM, which further improves the GHG balance sheets.
  • a mixing of wood and digestate for fuel production is particularly advantageous if only so the statutory emissions can be met.
  • the embodiment of Figure 39 corresponds to the system described in Figure 38, but supplemented by the recuperation of the ash of the digestate pellets or the mixed pellets.
  • the ash of the spent fermentation residual pellets and / or the mixed pellets is collected and fed as a valuable fertilizer component of a fertilizer production (see claim 1).
  • the advantages of energetic use are thus the great advantages of an almost closed nutrient cycle.
  • the fuel pellets continue to replace fossil fuel (heating oil, coal or natural gas).
  • the plants were selected according to the invention, which have the highest conversion rates and the lowest capital expenditure, ie the best combination of substrate efficiency and system efficiency and thus the best overall efficiency. These are the plants for anaerobic bacterial fermentation (see claim 8).
  • substrate substrates are already selected for fermentation substrates which do not or only to a minor extent have greenhouse gas emissions: greenhouse gases-free residues, including solid manure, low-greenhouse bio-waste and renewable raw materials, which are preferably greenhouse-friendly during cultivation. are low in gas (see claims 13).
  • the entire plant with all its plant modules is designed so that the BioMethan ends up being greenhouse gas negative (eg by using the optional plant modules "nutrient extraction” and / or “fuel production” or by an appropriate selection of the energy and energy sources to be used in the various plant modules or by dividing the biogas into the 3 utilization strands or by using the "C0 2 sequestration” system module) and the aim is "greenhouse gas-free CBM", then the proportion of greenhouse gas-intensive renewable resource can be increased to the fresh mass, so far Until the greenhouse gas load of the product "BioMethan” just does not tilt from negative to positive, that means maize and green rye are also suitable as a fermentation substrate, because corn and green rye have the advantages of high yields per hectare and high availability.
  • GHG-negative bio-methane or a corresponding natural gas equivalent produced by this process is used as fuel for the wheeled or telescopic loader used, so that the greenhouse gas emissions of the likewise used fuels natural gas and diesel are compensated (cf claim 1) ).
  • Stationary conveyors are electrically operated. THG-reduced, preferably THG-free, current is used for this purpose (compare claim 1).
  • biogas distribution By drawing in the diverter "biogas distribution" into the overall plant, a flexible control or regulation of the respective biogas components is possible, so that the generation of the various energy sources can be adapted to the changing conditions.Technically, the control of the biogas flow by simple valves in the corresponding gas lines.
  • volume effects occur in the case of several plant modules. It is therefore in each embodiment of advantage to build the largest possible biogas plants and operate (see claim 1 1).
  • GHG-reduced preferably GHG-poor, especially GHG- free and in particular GHG-negative BioMethan be produced whose GHG reduction effect compared.
  • Natural gas (CNG) is at least 100 or 180 or 236 or 336 gC0 2 - equivalents / kWh of methane.
  • the GHG negative bio methane can then be mixed with fossil and thus greenhouse gas loaded natural gas (CNG; THG load well-to-wheel at 236 gC0 2 -equivalent / kWhcNG) so that the resulting mixed gas can handle any GHG pollution between -468 gC0 2 -equivalent / kWli ischgas and +236 gC0 2 -equivalent / kWliMischgas has.
  • CNG greenhouse gas loaded natural gas
  • THG load well-to-wheel at 236 gC0 2 -equivalent / kWhcNG greenhouse gas loaded natural gas
  • the new plants can produce a whole range of mixed gases with different GHG reductions as well as an absolutely GHG-free mixed gas and even various GHG-negative mixed gases. These mixed gases can be used as fuel in traffic.

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Abstract

L'invention concerne un procédé et des installations pour générer un biogaz à émission réduite de gaz à effet de serre, pour préparer ce biogaz de manière à obtenir un biométhane à émission réduite de gaz à effet de serre ainsi que du dioxyde de carbone renouvelable (CO2), pour mélanger du biométhame à émission réduite de gaz à effet de serre et du gaz naturel (CNG) en vue d'obtenir un gaz mixte à émission réduite de gaz à effet de serre et pour utiliser le biométhane à émission réduite de gaz à effet de serre et/ou le gaz mixte à émission réduite de gaz à effet de serre en tant que sources d'énergie à émission réduite de gaz à effet de serre, en particulier en tant que carburant générant une émission réduite de gaz à effet de serre dans la circulation.
EP11704934A 2010-02-17 2011-02-16 Procédé et installation pour produire du biométhane comprimé (cbm) utilisé en tant que carburant à émission réduite de gaz à effet de serre Withdrawn EP2536839A1 (fr)

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DE102010017818A DE102010017818A1 (de) 2010-02-17 2010-07-08 Verfahren und Anlage zur Herstellung von CBM (Compressed BioMethane) als treibhausgasfreier Kraftstoff
PCT/EP2011/000748 WO2011101137A1 (fr) 2010-02-17 2011-02-16 Procédé et installation pour produire du biométhane comprimé (cbm) utilisé en tant que carburant à émission réduite de gaz à effet de serre

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WO2018065591A1 (fr) 2016-10-07 2018-04-12 Marc Feldmann Procédé et système pour améliorer les performances de réduction des émissions de gaz à effet de serre des biocombustibles et des biocarburants et/ou pour enrichir en carbone organique les surfaces consacrées à l'agriculture

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