Dual-mode production of syngas and downstream products thereof

Abstract

A dual-mode process and system to produce sustainable syngas and downstream products thereof are provided.

Description

BASF SE 240445W001- 1 - Dual-Mode Production of Syngas and Downstream Products ThereofField of the InventionThis invention relates to a process and a system to produce syngas and downstream products therefrom.Background of the InventionFor decades, fossil carbon resources like coal, oil, and gas have been extensively used as the predominant raw material for energy production and petrochemical processes. This has led to an enormous increase of the carbon dioxide (CO2) concentration in the atmosphere causing global warming and climate change. In view of the finite availability of fossil resources and the urgency to reduce CO2 emissions, there is a high need to replace fossil carbon resources by renewable and recycled carbon resources.Thus, chemical starting materials made from waste and biomass are becoming increasingly important for the transition to a more sustainable use of resources in the (petro-)chemical industry. Syngas, being mainly a mixture of hydrogen (H2) and carbon monoxide (CO) in varying molar ratios, but also comprising CO2, is among the most important of such starting materials; it can be obtained from waste and / or biomass, e.g., by gasification processes. Syngas is an essential starting material to synthesize downstream products which are produced in large quantities, e.g., methanol, synthetic natural gas (mainly methane), and Fischer-Tropsch hydrocarbons. Therefore, a continuous production mode and a continuous stream of syngas with controlled properties, in particular regarding the relative concentrations of H2, CO, and CO2, is generally advantageous.Regularly, it will be necessary to adjust the H2-to-CO / CO2 ratio in the syngas in order to fulfill the stoichiometric requirements for subsequent syngas-utilizing processes. This may be achieved, for instance, by admixing H2 to the syngas; advantageously, said H2 originates from sustainable sources, e.g., from water electrolysis driven by renewable energy sources. However, in particular solar and wind energy are subject to substantial fluctuations which leads to challenges to provide a stable minimum H2 supply and consequently a continuous syngas stream of defined composition. On the other hand, there may be an oversupply of H2 from water electrolysis such that more H2 is available than is needed to fully convert the carbon oxides in the syngas to downstream products.Thus, there is a need for improved processes to provide a syngas output in a stable and reliable manner while at the same time making optimum use of sustainable resources and energy sources.EP 3031 884 A1 relates to a method for the thermochemical conversion of a carbonaceous material feedstock into a synthesis gas in order to produce a fuel or a fuel or another product of interest, comprising an intermediate step to be chosen from one of the following three intermediate steps a) to c): a) upstream of the decarbonation step, the synthesis gas is subjected to a water gas reaction step (WGS), or b) downstream of the gas purification step, hydrogen produced by electrolysis of water is added to the synthesis gas, or c) downstream of the gas purification step, a mixture of synthesis gas and hydrogen produced by electrolysis of water is subjected to a reverse water gas reaction step (RWGS), the choice of one or other of steps a) to c) being made according to the cost of the electricity required for the production of hydrogen by electrolysis of water.US 2012 / 0123000 A1 relates to an assembly for producing at least one synthetic hydrocarbon from at least one inflowing stream of carbon monoxide and one inflowing stream of carbon dioxide. The assembly includes an electrolyzerBASF SE 240445W001- 2 -provided for producing a first stream of hydrogen, a first conversion unit provided for producing an intermediate stream of carbon monoxide from at least one portion of the inflowing stream of carbon dioxide and hydrogen (RWGS), a reactor for synthesizing said synthetic hydrocarbon; a second conversion unit provided for producing a second stream of hydrogen from carbon monoxide and water (WGS), the second hydrogen stream being directed towards the synthesis reactor; a guide assembly provided for selectively distributing the inflowing stream of carbon monoxide between the second conversion unit and the synthesis reactor, and for selectively distributing the first hydrogen stream between the first conversion unit and the synthesis reactor; a control unit provided for controlling the guide assembly.Ralph-Uwe Dietrich et al., Biomass and Bioenergy 111 (2018) 165- 173 relates to cost calculations for three different approaches of biofuel production using biomass, electricity and CO2. The three approaches are: The conversion of biomass (Biomass-toLiquid, BtL), the combination of renewable power and biomass (Power-and-Biomass-to-Liquid, PBtL) and the conversion of carbon dioxide with hydrogen from renewable power (Power-to-Liquid, PtL).Summary of the InventionIn a first aspect, the present invention relates to a process to produce syngas, wherein said process can operate in at least two distinct operation modes,wherein a first operation mode comprises the steps:A) providing at least one feedstock for gasification, the feedstock comprising biomass and / or waste;B) subjecting said feedstock to gasification to obtain raw syngas, comprising H2, CO, and CO2,C1) subjecting said raw syngas to a water-gas shift reaction to obtain H2-enriched syngas; andD1) separating and storing at least a portion of the CO2 comprised in said H2-enriched syngas to obtain a first adjusted syngas stream;andwherein a second operation mode comprises the steps A) and B), optionally comprises step C1), wherein the extent of the water-gas shift reaction is lower than in the first operation mode, and further comprises the steps: C2) carrying out water electrolysis, preferably using electrical power generated at least in part from non-fossil sources, to obtain hydrogen; andD2) admixing at least a portion of the hydrogen obtained in step C2) to the raw syngas obtained in step B) or to the H2-enriched syngas obtained in optional step C1) to obtain a second adjusted syngas stream;orwherein a second operation mode comprises the steps A) and B) and further comprises the steps:C2) carrying out water electrolysis, preferably using electrical power generated at least in part from non-fossil sources, to obtain hydrogen; andD3) admixing at least a portion of the hydrogen obtained in step C2) and admixing additional CO2, preferably at least a portion of the CO2 from step D1), to the raw syngas obtained in step B) to obtain a second adjusted syngas stream.In a second aspect, the invention relates to a system for producing syngas, the system comprising the units I) gasification unit;II) water-gas shift unit;BASF SE 240445W001- 3 - III) CO2 capture unit;IV) CO2 storage unit;V) water electrolysis unit; andVI) mixing unit.In a third aspect, the invention relates to a process to operate a system for producing syngas, said process comprising the steps51) operating the system in a first operation mode for a first period of time;52) switching the operation mode at the end of said first period of time from said first operation mode to a second operation mode, wherein said second operation mode is not identical to said first operation mode;53) operating the system in a second operation mode for a second period of time;54) switching the operation mode at the end of said second period of time from said second operation mode back to said first operation mode.Further aspects of the present invention will become apparent to the person skilled in the art directly from the foregoing and following description.General Terms and Definitions"Syngas” also known as "synthesis gas” refers to a mixture of predominantly CO and H2, which in addition may comprise further components such as CO2, water, and methane.The term "sustainable”, as used herein, mainly refers to environmental sustainability. It relates to practices, actions, and attributes suited to maintain and preserve the health and balance of natural ecosystems and resources over the long term such that their capacities to regenerate are not exceeded, e.g., by minimizing resource depletion, pollution, waste production, and greenhouse gas emissions. When referring to resources and energy sources, the term "sustainable” includes the terms renewable (e.g., derived from biomass, "bio-based”), recycled (e.g., derived from waste, "recycling-based”), and non-fossil (e.g., not derived from natural gas, oil, coal etc).The term "dual-mode” referring to a process means that said process can operate in two distinct modes or configurations ("operation modes”) to produce different products, to produce the same products via different process routes (e.g, different process steps or different process parameters) or in different volumes, or to achieve different objectives. In a dual-mode process, the same equipment or production line may be used to produce multiple products, to implement different process routes, or to perform different functions. Thus, dual-mode processes are often run in "flexible manufacturing systems”. The term dual-mode encompasses but is not limited to the term "simultaneous-mode”.The term "simultaneous-mode” referring to a process means that said process can operate in two distinct modes or configurations (i.e., it is a dual-mode process) and said two or more routes or configurations are combined and operated concurrently, e.g., with different weighting.A "flexible manufacturing system” is a manufacturing system that is designed to be versatile and adaptable, capable of running dual-mode processes, e.g., to produce multiple products, to follow different process routes, to achieve different objectives, or to handle different production volumes (i.e., to work at different levels of the operational capacity). A flexible manufacturing system may include a set of units, devices, machines, or workstations that are controlled byBASF SE 240445W001- 4 -a central computer system. The computer system can be programmed to direct the machines to produce different products or perform different operations, allowing the system to operate in different modes.The term ''equipped to'' as used herein means that a device, unit, or system has the necessary components, tools, mechanisms, features, or capabilities that enable it to carry out the specified operations, tasks, or functions and that it may be configured to do so.The term “fluidically connected to'' in respect to at least two units means that a fluid can flow from one unit to the other, e.g., through a system of one or more pipes, e.g., driven by screw conveyors, extruders, or pumps.The terms ''downstream of and ''upstream of, respectively, refer to a relationship of at least two operations or units within a sequence of operations or units and designate a connection of said operations or units in or against the direction, respectively, of material streams passing said sequence.The terms ''at least in part” or ''at least a part of or ''at least a portion of refer to a fraction that is nonzero. It includes any fractions larger than 0 %, e.g., at least 1 ppb, at least 1 ppm, at least 1 %o, at least 1 %, at least 5 %, at least 10 %, at least 20 %, at least 30 %, at least 40 %, at least 50 %, at least 60 %, at least 70 %, at least 80 %, at least 90 %, and 100 %. Said fraction may be determined, calculated, or evaluated on the basis of a certain observation period, e.g., on an hourly, daily, weekly, monthly, or annual basis, or on the basis of a production cycle or batch manufacturing. The terms "comprise(s)'', ''comprising'' etc. are inclusive of and may, in a preferred embodiment, be replaced by the terms "consist(s) of, "consisting of etc.Brief Description of the DrawingsFIG 1 : Flow diagram showing a process to produce syngas in a first mode.FIG 2: Flow diagram showing a process to produce syngas in a second mode.FIG 3: Flow diagram showing a process to produce syngas in simultaneous mode.FIG 4: System for performing the processes according to FIGs 1-3Legend for FIG 1-4:1 : feedstock; 2: raw syngas; 3a: H2-enriched syngas; 3b: CO2-depleted syngas; 4: CO2; 5: adjusted syngas; 6: downstream product; 7: water; 8: hydrogen; 9: oxygen11: gasification; 12: WGS; 13: CO2 capture; 14: CO2 storage; 15: downstream conversion; 16: electrolysis 101: gasification unit; 102: WGS unit; 103: CO2 capture unit; 104: CO2 storage unit; 105: mixing unit; 106: downstream conversion unit; 107: water electrolysis unitDetailed Description of the InventionThe present invention provides a dual-mode process and a system to produce syngas and downstream products thereof, preferably methanol as first downstream product.Said process starts with the gasification of a feedstock, preferably of sustainable origin, e.g., of biomass. To facilitate and optimize the gasification process, the feedstock may need to be pre-treated mechanically and / or chemically. The gasification process delivers a raw syngas that is normally purified to remove unwanted components. The furtherBASF SE 240445W001- 5 -handling and processing of this purified syngas may proceed according to at least one of two different routes, i.e. , in dual-mode.For the intended chemical use of the syngas, the H2-to-CO molar ratio typically requires further adjustment. For instance, for methanol synthesis, a ratio of approximately 2:1 is needed; for methane synthesis, higher ratios H2-to-CO must be achieved. Even more H2 in the syngas will be needed in case the syngas comprises substantial amounts of CO2 that have to be converted in addition to CO. However, the H2-to-CO ratio that is obtained from biomass gasification is often well below such values. Thus, there is a need to increase the H2 content of the syngas.In a first mode, the process comprises the water-gas shift (WGS) reaction of the (optionally purified) raw syngas to obtain H2-enriched syngas along with the separation and storage of carbon dioxide. The feedstock gasification and subsequent WGS may be run at full capacity of the manufacturing system in this mode. In particular, this mode may apply to situations where there are no well-suited alternatives to sufficiently enrich the syngas with H2 from sustainable external sources, e.g., from water electrolysis run by sustainable energy. For instance, this may be the case when there is not enough solar energy (during the night or cloud cover) or not enough wind energy (during calm or due to seasonal influences) available or both (during dark doldrums).In a second mode, the process comprises water electrolysis to produce H2, preferably "green H2” by using renewable energy, and admixing it to the (optionally purified) raw syngas. Also, CO2, preferably CO2 stored according to the first mode of the process, may be fed into the syngas. This carbon-enrichment via CO2 allows to run the feedstock gasification at partial, i.e., not at full, capacity of the manufacturing system while achieving the same quantitative syngas output as the first operation mode (the quantitative output being determined, calculated, or evaluated on the basis of a certain observation period, e.g., on a daily, weekly, monthly, or annual basis, or on the basis of a production cycle, batch manufacturing, or number of switches (e.g., one) between the two modes, e.g., the quantitative output being given as tons of carbon per hour). On the other hand, if there is an abundancy of green hydrogen from electrolysis, additional CO2 admixture may increase the quantitative syngas output of the second mode beyond the one of the first mode. In particular, this second mode applies to situations where there is enough sustainable energy available, e.g., from solar (during daylight, sunshine) or wind power plants, to produce H2 from water via electrolysis.The process according to the invention is a dual-mode process in which it is possible to switch between different operation modes. The switch between said first and second operation mode may be performed on the basis of a predefined schedule, e.g., as a twice-daily switch between day-mode and night-mode according to sunrise and sunset, optionally modulated to account for seasonal effects, e.g., summer schedule and winter schedule. Alternatively, the switch between said modes may be controlled with the help of monitoring external factors relevant for the provision of renewable energies, in particular solar and wind power, e.g., by measuring or forecasting relevant weather parameters like sunshine hours or suitable wind speeds. In any case, details of said switch will depend on the type of energy source that is used and the respective influencing factors.Importantly, steps or sub-steps of said first and second operation mode may be combined and run concurrently in a simultaneous mode. In particular, H2 from water electrolysis may be admixed to the H2-enriched syngas obtained by WGS reaction, with CO2 capture and storage. Such simultaneous modes may be advantageous, for instance, where operating the process in one distinct mode only does not provide enough adjusted syngas, e.g., due to insufficient availabilities of feedstock or (renewable) energy resources.BASF SE 240445W001- 6 - Running the process according to the invention in one of these two modes (full-capacity biomass gasification along with WGS and CO2 separation and CO2 storage compared to full-capacity or partial-capacity biomass gasification along with water electrolysis and H2 and CO2 admixture) allows for a steady and continuous syngas supply to downstream processes. Furthermore, fluctuations in the supply with renewable energies for the water electrolysis may be compensated: For instance, energy supply dips for H2 production may be balanced by increased gasification and WGS. In turn, energy supply peaks may be used to reduce the feedstock gasification and to increase the syngas fraction that originates from H2 and CO2, thus reducing the feedstock demand (for a certain observation period, e.g., daily, weekly, monthly, or annual, or on the basis of a production cycle, batch manufacturing, or number of switches between the two modes). Alternatively, energy supply peaks may be used to produce even more hydrogen and admixing it to syngas along with stored CO2, and thus temporarily increasing the syngas output. Accordingly, the process may also reduce the need for intermediate energy storage. Overall, the dual-mode process of the invention allows for a highly resource-efficient production of syngas and for a flexibilization of the syngas production process in that the impact of changing framework conditions (e.g., supply with gasification feedstock, supply with renewable energy) may be dampened.Of note, it is conceived within the scope of this invention that the WGS reaction, CO2 separation and storage, water electrolysis, admixture of hydrogen and / or 002 to the syngas, or parts thereof may be run concurrently, i.e., at the same time ("simultaneous mode”). In particular, the WGS reaction, water electrolysis and H2 admixture to the H2 enriched syngas from the WGS reaction may be conducted in one mode of operation. This is carried out with 002 capture and storage and 002 admixture to the H2 enriched syngas from the WGS reaction, respectively. This may be advantageous, for instance, where running the process in one mode only does not provide enough adjusted syngas, e.g., due to insufficient availabilities of feedstock or (renewable) energy resources.The produced syngas exhibits favorable sustainability properties, e.g., it is characterized by a low carbon footprint, in the case of long-lived products even by net-negative carbon dioxide emissions. This is because the carbon atoms contained in said products are preferably bio-based or recycling-based. Also, the capture, storage, and later use of carbon dioxide from the gasification and WGS reaction ensures a more complete conversion of the gasification feedstock to syngas in terms of carbon atom economy. Furthermore, the hydrogen used for the syngas adjustment originates from water electrolysis preferably driven by sustainable energy such that the use of fossil resources and greenhouse gas emissions are reduced. The same sustainability considerations apply also to the attributes of the downstream products of the obtained syngas, in particular to methanol, FT hydrocarbons, and methane.Thus, in a first aspect, the present invention relates to a process to produce syngas, wherein said process can operate in at least two distinct operation modes,wherein a first operation mode comprises the steps:A) providing at least one feedstock for gasification, the feedstock comprising biomass and / or waste;B) subjecting said feedstock to gasification to obtain raw syngas, comprising H2, CO, and C02,C1) subjecting said raw syngas to a water-gas shift reaction to obtain H2-enriched syngas; andD1) separating and storing at least a portion of the C02 comprised in said H2-enriched syngas to obtain a first adjusted syngas stream;BASF SE 240445W001- 7 -andwherein a second operation mode comprises the steps A) and B), optionally comprises step C1), wherein the extent of the water-gas shift reaction is lower than in the first operation mode, and further comprises the steps: C2) carrying out water electrolysis, preferably using electrical power generated at least in part from non-fossil sources, to obtain hydrogen; andD2) admixing at least a portion of the hydrogen obtained in step C2) to the raw syngas obtained in step B) or to the H2-enriched syngas obtained in optional step C1) to obtain a second adjusted syngas stream;orwherein a second operation mode comprises the steps A) and B) and further comprises the steps:C2) carrying out water electrolysis, preferably using electrical power generated at least in part from non-fossil sources, to obtain hydrogen; andD3) admixing at least a portion of the hydrogen obtained in step C2) and admixing additional CO2, preferably at least a portion of the CO2 from step D1), to the raw syngas obtained in step B) to obtain a second adjusted syngas stream.The sets of preferred embodiments described in the following are intended to further illustrate, but in no way to restrict the present invention as described herein. They represent a suitably structured part of the description and thus support, but do not represent the claims of the present invention.Preferred Embodiments1.1) The process according to the first aspect of the invention.1.2) The process according to the preceding embodiment, wherein said process is carried out in a flexible manufacturing system.1.3) The process according to any of embodiments 1.1 to 1.2, wherein the quantitative output per unit of time of said second adjusted syngas stream is approximately the same as the quantitative output per unit of time of said first adjusted syngas stream.1.4) The process according to any of embodiments 1.1 to 1.2, wherein the quantitative output per unit of time of said second adjusted syngas stream is higher than the quantitative output per unit of time of said first adjusted syngas stream.1.5) The process according to any of the preceding embodiments, wherein the amount of feedstock that is gasified in step B) in said first operation mode is higher than in said second operation mode.1.6) The process according to any of the preceding embodiments, wherein the switches between the first operation mode and the second operation mode and vice versa are performed according to a pre-defined schedule, preferably the operation mode is changed twice per day.1.7) The process according to any of the preceding embodiments, wherein the switches between said first operation mode and said second operation mode and vice versa are performed according to a monitoring of external factors relevant for the provision of renewable energies.1.8) The process according to any of the preceding embodiments, wherein the process can further operate in a simultaneous mode, said simultaneous mode comprising the steps A), B), C1), C2), and D1), and comprising step D2)BASF SE 240445W001- 8 - or D3), wherein in step D2) and D3), respectively, said hydrogen and CO2, respectively, are admixed to the raw syngas obtained in step B) or to the H2-enriched syngas obtained in step C1).Step A)In a first step of the process according to the invention, a feedstock suitable for gasification is provided. Said feedstock is preferably a solid or liquid material or a mixture of such materials. It may comprise organic compounds and / or organic polymers, in particular of bio-based or recycling-based origin. The feedstock may further contain impurities such as inorganic and metallic components. Preferably, the feedstock is selected from the group comprising biomass, waste, fossil feedstocks, and mixtures thereof.Biomass is biological material derived from living or recently living organisms. The biomass to be provided in step A) may be any material of vegetable or animal origin that is in principle suitable to be gasified to syngas. In particular, the term "biomass” comprises plants or parts thereof like crops, energy crops, wood, wood waste, wood pellets, wood chips, forestry and agricultural residues, straw, lignocellulosic biomass, or residues thereof, marine organisms (like algae), biobased oils, biobased fats (preferably hydrated), and biowaste such as organic food waste. Of note, the biomass provided may be composed of biomass streams from various of the above-mentioned sources.The term "waste” comprises fossil-based waste, biobased waste, and mixtures thereof. Examples for waste suitable as a feedstock are agricultural / farming residues such as wood processing residues, waste wood, logging residues, switch grass, discarded seed corn, corn stover and other crop residues, municipal solid waste (MSW), textiles, industrial waste, sewage sludge, (mixed) plastic waste, packaging waste, shredder residues such as automotive shredder residues, pyrolysis oils, and mixtures thereof.The term "fossil feedstock” includes but is not limited to coal, oil, natural gas, petcoke, carbonaceous products from crude oil refining, extra heavy crude oil, tar sand, bitumen, coke, high vacuum residues (HVRs), methane and mixtures thereof.Preferably, the feedstock is selected from the group comprising biomass, municipal solid waste (MSW), shredder residues such as automotive shredder residues, textiles, plastic waste, packaging waste, and mixtures thereof.Preferred Embodiments1.9) The process according to any of the preceding embodiments, wherein in step A) the combined mass fraction of biomass and waste in said at least one feedstock for gasification is more than 20 %, preferably more than 40 %, more preferably more than 50 %, more preferably more than 60 %, more preferably more than 70 %, more preferably more than 80 %, more preferably more than 90 %.1.10) The process according to any of the preceding embodiments, wherein in step A), said at least one feedstock consists of biomass and / or waste.1.11) The process according to any of embodiments 1.1 to 1.9, wherein in step A), said at least one feedstock comprises at least one fossil feedstock, preferably selected from the group consisting of coal, oil, natural gas, petcoke, carbonaceous products from crude oil refining, extra heavy crude oil, tar sand, bitumen, coke, high vacuum residues (HVRs), methane, and mixtures thereofBASF SE 240445W001- 9 - preferably from the group consisting of coal, petcoke, carbonaceous products from crude oil refining, extra heavy crude oil, tar sand, bitumen, coke, high vacuum residues (HVRs), and mixtures thereof.1.12) The process according to any of the preceding embodiments, wherein in step A) said biomass is selected from the group consisting of plants or parts thereof like crops, energy crops, wood, wood waste, wood pellets, wood chips, forestry and agricultural residues, straw, lignocellulosic biomass, or residues thereof, marine organisms, biobased oils, biobased fats, biowaste, and mixtures thereof.1.13) The process according to any of the preceding embodiments, wherein in step A) said waste is selected from the group consisting of fossil-based waste, biobased waste, and mixtures thereof,preferably from the group consisting of agricultural / farming residues such as wood processing residues, waste wood, logging residues, switch grass, discarded seed corn, corn stover and other crop residues, municipal solid waste (MSW), textiles, industrial waste, sewage sludge, (mixed) plastic waste, packaging waste, shredder residues such as automotive shredder residues, pyrolysis oils, and mixtures thereof,more preferably from the group consisting of municipal solid waste, textiles, plastic waste, packaging waste, shredder residues, pyrolysis oils, and mixtures thereof.Step B) according to this invention comprises the gasification of the feedstock provided in step A) to obtain syngas. Optionally, step B) also includes the pre-treatment of the feedstock as well as the purification of the produced raw syngas stream to obtain purified syngas.Pre-treatmentFeedstocks may be pre-treated according to a suitable pre-treatment method or a suitable combination of more than one pre-treatment methods with the aim to homogenize the physical and chemical properties of the feedstock, to meet certain requirements for a specific type of gasifier, and / or to meet certain requirements for further downstream process steps to produce chemical compounds.Suitable pre-treatment methods for a given feedstock are preferably selected from the group comprising drying, comminution, classification, sorting, agglomeration, (thermo-)chemical methods, and biological methods.Drying methods comprise belt drying, fluidized bed drying, drum drying, spray drying, hearth drying, rotary tray drying, and radiation drying.Comminution methods comprise pressure, impact, shearing, grinding, milling, shredding, crushing, and cutting. Grinding a feedstock may be carried out, e.g., in rod mills and ball mills, closed circuited with classification. Milling is preferably performed in a wet state. Accordingly, a grinding pre-treatment is preferably combined with a drying method in a single pre-treatment unit. Crushing may be performed in jaw-crushers, gyratory crushers, and cone crushers. Crushing is preferably performed in a dry state. Accordingly, a crushing pre-treatment is preferably combined with a drying method prior to crushing in a single pre-treatment unit.Classification methods comprise screening (e.g., with revolving drum screens, surface screens, fixed and movable gratings), winnowing, flotation, zigzag classification, and air table classification. Screening systems preferably comprise one or more of bar screens, wedge wire screens, radial sieves, banana screens, multi-deck screens, vibratory screens,BASF SE 240445W001- 10 -fine screens, flip flop screens, and wire mesh screens. Screens can be static, or they can incorporate mechanisms to shake or vibrate the screen(s).Sorting methods comprise manual sorting, pneumatic sorting, sensor-based sorting (e.g., NIR-assisted sorting, induc-tive-assisted sorting, and X-ray-assisted sorting), and metal separation (e.g., magnetic separation, eddy current separation).Agglomeration methods comprise pelletizing, briquetting, and extrusion. Such methods usually comprise a means for compressing the feedstock and optionally a further means for heating ("baking”) the compressed feedstock. Such pretreatment methods often provide better physical characteristics than the initial feedstock, improve the transportability of the feedstock, e.g., to another location, and improve the thermochemical behavior.Thermochemical methods comprise pyrolysis, converting the feedstock into char, and torrefaction. Thermochemical pre-treatment may be carried out in pyrolysis reactors in which the feedstock is heated to e.g., 500 °C in an inert atmosphere to obtain a pyrolysis oil having an improved calorific value compared to the untreated feedstock and a reduced volume which improves the transportability of the feedstock, e.g., to another facility.In particular, biomass is preferably torrefied or converted by pyrolysis into a pyrolysis oil prior to gasification.Municipal solid waste (MSW) is optionally pre-treated by methods such as drying, shredding, sorting, inert removal and may be used in the form of refuse-derived fuel (RDF).Biological methods comprise fermentation such as anaerobic fermentation.GasificationThe gasification step is performed in a gasifier to produce raw syngas from the (optionally pre-treated) feedstock. The selection of reactor type and size depends on several parameters, including the composition of the carbonaceous feedstock, physical and / or chemical properties of the feedstock like water content, ash content, elemental composition, size, and calorific value, the demand of products, and the availability of the carbonaceous feedstock. It also depends on the pre-treatment method applied to the feedstock. An overview of gasifier types is for example provided in James G. Speight, Handbook of Gasification Technology, Scrivener Publishing and Wiley, 2020, chapter 8.4.2, pp. 259-262. Preferably, the gasifier is selected from the group comprising counter-current fixed bed reactors, co-current-fixed bed reactors, bubbling fluidized bed reactors, circulating fluidized bed reactors, dual fluidized bed reactors, downdraft entrained flow reactors, updraft entrained flow reactors, and plasma gasifiers like fixed-bed plasma gasifiers.More preferably, the gasifier is selected from the group comprising bubbling fluidized bed reactors, circulating fluidized bed reactors, dual fluidized bed reactors, downdraft entrained flow reactors, and updraft entrained flow reactors, and fixed-bed plasma gasifiers.While gasifiers typically rely on heat generation by (partial) oxidation, in particular plasma gasifiers, e.g., their plasma torches, may be operated with electrical power. Preferably, said electrical power is generated from sustainable or renewable sources, more preferably from at least one source selected from the group consisting of solar energy, wind energy, tidal energy, nuclear energy, geothermal energy, and combinations thereof.Preferred combinations of pre-treatment methods and gasifier types comprise:- screening and / or agglomeration with counter-current or co-current-fixed bed reactors;- crushing and / or shredding with bubbling, circulating, or dual fluidized bed reactors;BASF SE 240445W001- 11 - - grinding with downdraft or updraft entrained flow reactors.The gasification reaction in a gasifier is typically carried out at a temperature > 700 °C in the presence of a sub-stoichiometric amount of an oxidant such as oxygen, air, steam, supercritical water, CO2, or a mixture of the aforementioned. Oxygen is the most common oxidant used for gasification because of its easy availability and low cost. Preferably, the gasifier is an "oxygen blown" gasifier, i.e., oxygen is preferably used as the oxidant in suitable gasifiers listed above. For example, the molar ratio "oxygen : oxygen required for a total oxidation of the feedstock” can range from 0.3 to less than 1. It is particularly advantageous in terms of sustainability if as much of the needed oxygen as possible is supplied with the help of renewable energy sources, e.g., via water electrolysis driven by renewable energy, in particular from step 02) as described below. If steam acts as an oxidant, the raw syngas has a higher molar ratio H2-to-CO in comparison to the use of air as an oxidant.Gasification of the feedstock yields a raw syngas which consists primarily of H2 and CO, with minor amounts of CO2, methane, other hydrocarbons, and impurities. Said raw syngas has a molar ratio H2-to-CO when leaving the gasifier which ranges from about 0.1 : 1 to about 3 : 1 and depends on the type of solid and / or liquid feedstock used, the oxidant and other reaction conditions applied such as temperature and / or residence time of the reactants in the gasifier. The H2-to-CO / CO2 ratio may be described by the stoichiometric number S, defined as S = ([H2]-[CO2]) / ([CO2]+[CO]). For instance, the gasification of biomass or plastic waste typically delivers raw syngas with S in the range from 1 to 2. A gasification reaction usually results in further reaction products such as solid and / or highly viscous carbonaceous residues (e.g., ash, char, and / or tar).PurificationThe raw syngas obtained from gasification may be further treated to obtain purified syngas.In such purification steps, impurities and other undesired components are removed. Typical impurities in the raw syngas comprise acid gases, chlorides, sulfur-containing organic compounds such as sulfur dioxide, ammonia, trace heavy metals like mercury (e.g., as respective salts), tars / condensable hydrocarbons, and particulate residues like dust. Various chemical and / or physical methods for removal of such impurities from said raw syngas such as filtration, scrubbing, condensation and ab- / adsorption are known and can be chosen and adapted according to the type and respective concentration of the impurities in said raw syngas and the tolerance to such impurities in the successive process steps. E.g., bulk particulate impurities can be removed from the raw syngas by a cyclone and / or filters, fine particles, ammonia, and chlorides by wet scrubbing, trace heavy metals by solid absorbents, and sulfur-containing organic compounds (e.g., COS) by catalytic hydrolysis to H2S and acid gas removal. Bulky and fine particles such as dust in the syngas may also be removed with a quench in a soot water washing unit.Purification of raw syngas is preferred to improve the lifetimes and to maintain the activities of catalysts utilized in successive process steps and to meet environmental emission regulations.Preferred Embodiments1.14) The process according to any of the preceding embodiments, wherein step B) comprises at least one mechanical and / or chemical feedstock pre-treatment step, preferably selected from the group consisting of drying, comminution, classification, sorting, agglomeration, (thermo-)chemical methods, and biological methods.BASF SE 240445W001- 12 - 1.15) The process according to any of the preceding embodiments, wherein in step B) according to the first operation mode, said gasification is run at full capacity of the manufacturing system.1.16) The process according to any of the preceding embodiments, wherein in step B) according to the second operation mode, said gasification is run at partial capacity of the manufacturing system.1.17) The process according to any of the preceding embodiments, wherein in step B), said gasification is carried out in a gasifier, preferably selected from the group consisting of bubbling fluidized bed reactors, circulating fluidized bed reactors, dual fluidized bed reactors, downdraft entrained flow reactors, and updraft entrained flow reactors, and fixed-bed plasma gasifiers.1.18) The process according to any of the preceding embodiments, wherein in step B), said gasification is carried out by using oxygen as an oxidant, wherein preferably at least a portion of said oxygen is obtained from water electrolysis, in particular driven by renewable energy, more preferably at least a portion of said oxygen is obtained from step C2).1.19) The process according to any of the preceding embodiments, wherein step B) comprises at least one purification step of the raw syngas to obtain purified syngas, preferably selected from the group consisting of filtration, scrubbing, condensation, absorption, and adsorption.1.20) The process according to any of the preceding embodiments, wherein in step B),said raw syngas has a stoichiometric number in the range from 0.3 to 2.5, preferably in the range from 0.8 to 2.0, more preferably in the range from 1.1 to 1.9, more preferably in the range from 1.2 to 1.8, e.g., about 0.8, 0.9, 1.0, 1.1, 1.2, 1.3, 1.4, 1.5, 1.6, 1.7, 1.8, 1.9, or 2.0.Step C1)For many applications, the (optionally purified) raw syngas of step B) may need to be conditioned to adjust the H2-to-CO / CO2 ratio to meet downstream process requirements. For instance, biomass gasification may deliver syngas with a stoichiometric number of only slightly above 1, while for methanol production a stoichiometric number of slightly above 2 has been proven to be optimal. Such adjustment of the stoichiometric number may be achieved by the water-gas shift (WGS) reaction (followed by CO2 removal) represented by the following chemical reaction scheme:Thus, the H2 content in the syngas is increased by reacting at least a portion of the CO comprised in the raw syngas with water to form additional H2 and CO2 and thereby a H2-enriched syngas stream is generated. I.e., by the WGS reaction and subsequent (full or partial) CO2 removal (see step D1), syngas having a first stoichiometric number is converted to a H2-enriched syngas having a second stoichiometric number, wherein said second stoichiometric number is larger than said first stoichiometric number.The WGS reaction is an exothermic reaction. It is preferably performed according to processes known in the art, such as those defined in W.-H. Chen, et al, Applied energy 2020, 258, 114078. It can be conducted with a variety of catalysts (such as copper-zinc-aluminum catalysts and chromium or copper promoted iron-based catalysts) in the temperature range between about 200 °C and about 480 °C. The type of WGS reaction can be adapted to the general conditions and requirements of the process, e.g., how much additional H2 obtained by the WGS reaction is desired.BASF SE 240445W001- 13 - Details on the WGS equilibrium are described, e.g., in H. Hiller et al., Ullmann's Encyclopedia of Industrial Chemistry, 2012, Chapter "Gas Production, 1. Introduction” and R. Reimert et al., Ullmann's Encyclopedia of Industrial Chemistry, 2012, Chapter "Gas Production, 2. Processes”, and the references cited therein.Preferred Embodiments1.21) The process according to any of the preceding embodiments, wherein in step C1) according to the first operation mode, said WGS reaction is run at full capacity of the manufacturing system.1.22) The process according to any of the preceding embodiments, wherein in step C1) according to the second operation mode, said WGS reaction is run at partial capacity of the manufacturing system.Step D1)It may be further necessary to reduce the amount of CO2 comprised in the raw syngas or H2-enriched syngas to ensure or improve the efficiency and / or effectivity of downstream processes, in particular in cases where the amounts of hydrogen available are insufficient to reduce all of CO and CO2 in the syngas to the desired downstream products (e.g., methanol, FT hydrocarbons, or methane).CO2 separationCO2 formed in steps B) and / or C1) is removed at least in part from the H2-enriched syngas obtained in step C1) such that adjusted syngas with an even higher H2-to-CO / CO2 ratio is obtained ("CO2-depleted syngas”).A variety of processes to capture CO2 is available to the one of skill in the art; suitable methods for CO2 removal from syngas include membrane separation, cryogenic separation, absorption, adsorption, e.g., with pressure-swing-adsorp-tion (PSA) or metal organic frameworks (MOFs), and combinations thereof.In particular, CO2 may be removed from the syngas by absorption. The syngas is contacted with an aqueous solution of alkylamines such as monoethanolamine, diethanolamine, methyldiethanolamine and the like or methanol ("amine wash” or "methanol wash”). CO2 is captured in such solutions / liquids in a chemical reaction and then directed to a "regenerator” (e.g., a stripper with a boiler) where the absorption reaction is reversed such that CO2 and the recovered alkylamine are obtained.CO2 storageCaptured CO2 may be stored in liquid form. Prior to liquefaction, the CO2 may undergo purification and drying steps. Liquefaction is accomplished, e.g., by compression to 2-4 MPa and cooling to temperatures < 0 °C by a refrigerant. Optionally after additional purification, the liquid CO2 is sent to insulated vessels, typically of stainless steel, where it is stored at -18 °C and 2.1 MPa.Processes for the separation, liquefaction, and storage of carbon dioxide are described, e.g., in Topham et al., Ullmann's Encyclopedia of Industrial Chemistry, 2014, Chapter "Carbon Dioxide”, pp. 1-43.BASF SE 240445W001- 14 - Preferred Embodiments1.23) The process according to any of the preceding embodiments, wherein in step D1),said separation is accomplished by a process selected from the group consisting of membrane separation, cryogenic separation, absorption, or adsorption.1.24) The process according to any of the preceding embodiments, wherein in step D1),said storing comprises liquefaction and optionally purification of CO2.1.25) The process according to any of the preceding embodiments, wherein in step D1),said first adjusted syngas stream has a stoichiometric number in the range from 1.9 to 3.0, preferably in the range from 2.0 to 2.5, more preferably in the range from 2.0 to 2.2, most preferably of approximately 2.1 or approximately 2.2.Step C2)As mentioned for step C 1), the H2-to-CO ratio in the syngas may be increased by the WGS reaction. Alternatively, the amount of hydrogen may be raised by supplementing hydrogen from external sources, e.g., from water electrolysis, preferably using sustainable energy, in particular where (sustainable) energy is readily available.Electrolysis of water is an environmentally friendly method to produce hydrogen because it uses renewable H2O and produces only pure oxygen as by-product. Additionally, water electrolysis utilizes direct current (DC), preferably from sustainable energy resources, for example solar, wind, hydropower, and biomass.In the context of the present invention, hydrogen from water electrolysis may be admixed to syngas obtained in step B) in order to adjust the H2-to-CO ratio according to the needs of the overall process and to allow for a maximum conversion of carbon oxides to downstream chemicals. Also, oxygen from water electrolysis may be employed as an oxidant for the gasification according to step B).One suitable water electrolysis process is alkaline water electrolysis. Hydrogen production by alkaline water electrolysis is a well-established technology up to the megawatt range for a commercial level. In alkaline water electrolysis initially at the cathode side two water molecules of alkaline solution (KOH / NaOH) are reduced to one molecule of hydrogen (H2) and two hydroxyl ions (OH-). The produced H2 emanates from the cathode surface in gaseous form and the hydroxyl ions (OH-) migrate under the influence of the electrical field between anode and cathode through the porous diaphragm to the anode, where they are discharged to half a molecule of oxygen (02) and one molecule of water (H2O). Alkaline electrolysis operates at lower temperatures such as 30-80°C with alkaline aqueous solution (KOH / NaOH) as the electrolyte, the concentration of the electrolyte being about 20% to 30 %. The diaphragm in the middle of the electrolysis cell separates the cathode and anode and also separates the produced gases from their respective electrodes, avoiding the mixing of the produced gases. However, alkaline electrolysis has negative aspects such as limited current densities (below 400 mA / cm2), low operating pressure and low energy efficiency.Thus, preferably, hydrogen is provided by polymer electrolyte membrane water electrolysis. Variants of polymer electrolyte membrane water electrolysis are proton exchange membrane water electrolysis (PEMWE) and anion exchange membrane water electrolysis (AEMWE).PEM water electrolysis was developed to overcome the drawbacks of alkaline water electrolysis. PEM water electrolysis technology is similar to the PEM fuel cell technology, where solid polysulfonated membranes (Nation®,BASF SE 240445W001- 15 -fumapem®) are used as an electrolyte (proton conductor). These proton exchange membranes have many advantages such as low gas permeability, high proton conductivity (0.1 ± 0.02 S cm-1), low thickness (20-300 m), and allow high-pressure operation. In terms of sustainability and environmental impact, PEM water electrolysis is one of the most favorable methods for conversion of renewable energy to highly pure hydrogen. PEM water electrolysis has great advantages such as compact design, high current density (above 2 A cm-2), high efficiency, fast response, operation at low temperatures (20-80°C) and production of ultrapure hydrogen. The state-of-the-art electrocatalysts for PEM water electrolysis are highly active noble metals such as Pt / Pd for the hydrogen evolution reaction (HER) at the cathode and I rO2 / RuO2 for the oxygen evolution reaction (OER) at the anode.One of the largest advantages of PEM water electrolysis is its ability to operate at high current densities. This can result in reduced operational costs, especially for systems coupled with very dynamic energy sources such as wind and solar power, where sudden spikes in energy output would otherwise result in uncaptured energy. The polymer electrolyte allows the PEM water electrolyzer to operate with a very thin membrane (ca. 100-200 pm) while still allowing high operation pressure, resulting in low ohmic losses, primarily caused by the conduction of protons across the membrane (0.1 S / cm), and a compressed hydrogen output.The PEM water electrolyzer utilizes a solid polymer electrolyte (SPE) to conduct protons from the anode to the cathode while insulating the electrodes electrically. Under standard conditions the enthalpy required for the formation of water is 285.9 kJ / mol. One portion of the required energy for a sustained electrolysis reaction is supplied by thermal energy and the remainder is supplied through electrical energy.The half reaction taking place on the anode side of a PEM water electrolyzer is commonly referred to as the Oxygen Evolution Reaction (OER). Here the liquid water reactant is supplied to a catalyst where it is oxidized to oxygen, protons, and electrons.The half reaction taking place on the cathode side of a PEM water electrolyzer is commonly referred to as the Hydrogen Evolution Reaction (HER). Here the protons that have moved through the membrane are reduced to gaseous hydrogen.PEMs can be made from either pure polymer membranes or from composite membranes, where other materials are embedded in a polymer matrix. One of the most common and commercially available PEM materials is the fluoropolymer PFSA, or Nation®, a DuPont product. While Nation® is an ionomer with a perfluorinated backbone like Teflon, there are many other structural motifs used to make ionomers for proton-exchange membranes. Many use polyaromatic polymers, while others use partially fluorinated polymers.An overview of hydrogen production by PEM water electrolysis is given in S. Kumar and V. Himabindu, Material Science for Energy Technologies 2 (2019), pp. 4442 - 4454.An overview of hydrogen production by anion exchange membrane water electrolysis is given in H. A. Miller et al., Sustainable Energy Fuels, 2020, 4, pp. 2114 - 2133.Preferably, the electrical power is generated at least in part from non-fossil, renewable resources.Thus, preferably, the electrical power is generated at least in part from wind power, solar energy (thermal, photovoltaic and concentrated solar power), hydroelectricity (tidal power, wave power, hydroelectric dams, in-river-hydrokinetics), geothermal energy, ambient or industrial heat captured by heat pumps, bioenergy (biofuel, biomass), the renewable part of waste energy sources or nuclear energy (fission).BASF SE 240445W001- 16 - Preferred Embodiments1.26) The process according to any of the preceding embodiments, wherein in step C2), said water electrolysis is carried out as PEM water electrolysis.1.27) The process according to any of the preceding embodiments, wherein in step C2), electrical power is used for said water electrolysis and the fraction of said electrical power that originates from fossil energy sources is < 50%, preferably < 30%, more preferably < 20%, even more preferably < 10%, most preferably < 1 %.1.28) The process according to any of the preceding embodiments, wherein in step C2), electrical power is used for said water electrolysis and at least a part, preferably all, of said electrical power originates from non-fossil energy sources, preferably selected from the group consisting of wind energy, solar energy, hydropower, geothermal energy, ambient or industrial heat captured by heat pumps, bioenergy (biofuel, biomass), the renewable part of waste energy sources, or nuclear energy, more preferably selected from the group consisting of wind energy and solar energy.Steps D2) and D3)In steps D2) and D3), respectively, H2 and CO2 are admixed to the raw syngas obtained in step B). Thus, the overall output of syngas is increased, additional CO2, e.g., from step D1), preferably of biobased or recycled origin, is made available for conversion to downstream products, and the H2-to-CO / CO2 ratio is adjusted to meet the downstream conversion process requirements.For mixing syngas, H2, and CO2, the components are fed in gaseous form into a mixing unit where they are combined in the appropriate ratios such that an enriched syngas is formed. Said enriched syngas leaves the mixing unit and is provided to downstream processes which it is suitable for.The CO2 is stored according to step D1), and gaseous CO2 can be removed directly from the gas phase of the storage vessel and / or, in case of higher demands, may be generated from the liquid phase by a steam, hot water, or electrically heated vaporizer.Of note, the CO2 amounts from step D1) that are admixed according to step D3) may be supplemented by CO2 amounts from other, preferably sustainable, sources, e.g., in case water electrolysis delivers more H2 than could otherwise be admixed to the syngas of step B) and 002 of step D1). Such additional 002 might be provided from further storage tanks, storage vehicles, or a pipeline system. Carbon dioxide may be captured from the atmosphere (direct air capture, DAO), from the ocean (direct ocean capture, DOC; indirect ocean capture, IOC), or from industrial point sources of carbon dioxide emissions (via pre-combustion capture, oxyfuel combustion, or post-combustion capture routes). Such industrial point sources include power plants based on combustion of organic material like coal, natural gas, oil, waste, or biomass and industrial facilities like plants for cement production, steel manufacturing, chemical manufacturing, biogas production and processing, and refineries. In the area of chemical manufacturing, steam crackers, steam reformers (especially to produce hydrogen), partial oxidation plants (e.g., to obtain ethylene oxide, acetylene, or syngas), and facilities for the hydrotreatment of bio-oils or waste-derived pyrolysis oils are among the main facilities that emit significant amounts of carbon dioxide. Preferably, the carbon dioxide used in the processes according to the present invention, is obtained from sustainable sources, more preferably from renewable sources, e.g., fromBASF SE 240445W001- 17 -biomass. Processes for capturing carbon dioxide are described for examples in S. Topham et al., Ullmann's Encyclopedia of Industrial Chemistry, 2014, Chapter "Carbon dioxide”, and the references cited therein.Preferred Embodiments1.29) The process according to any of the preceding embodiments, wherein in step D2) and D3), respectively, said second adjusted syngas stream has a stoichiometric number in the range from 1.9 to 3.0, preferably in the range from 2.0 to 2.5, more preferably in the range from 2.0 to 2.2, most preferably of approximately 2.1 or approximately 2.2.1.30) The process according to any of the preceding embodiments, wherein in step D3), at least a portion of said additional CO2 is obtained from step D1).1.31) The process according to any of the preceding embodiments, wherein in step D3), at least a portion of said additional CO2 originates from sustainable sources, in particular from biomass.1.32) The process according to any of the preceding embodiments, wherein in step D3), at least a portion of said additional CO2 is obtained via DAC, DOC, and / or IOC or is obtained via carbon capture from industrial point sources.Further process stepsThe process according to the invention may comprise further optional steps where needed or advisable to improve the overall performance of the process. In particular, purification steps may be applied to the streams obtained in steps A), B), C1) / C2), and D 1 ) / D2) / D3 to improve their properties or to meet certain specifications for further process steps. Also, steps E) and / or F), described hereinafter, may be comprised by the process of the invention.Also, it may be required or advantageous to first convert CO2 in the syngas under consumption of H2 to CO and H2O via the reverse WGS (rWGS) reaction, in particular where CO2 has not been removed from the syngas or has been deliberately added to generate a carbon-enriched syngas. rWGS reactions are described in Y. A. Daza et al., RSC Adv. 2016, 6, 49675-49691, and the references cited therein.In one embodiment of the process of the present invention, especially in the case when methanol is prepared as downstream product from the syngas, no rWGS of a stream comprising CO2 separated from the syngas stream obtained in step B or in step C1 is carried out.Preferred Embodiments1.33) The process according to any of the preceding embodiments, the process further comprising purification of at least a portion of the first adjusted syngas stream from step D1 ) and / or of at least a portion of the second adjusted syngas stream from steps D2) or D3).1.34) The process according to any of the preceding embodiments, the process further comprising subjecting at least a portion of the first adjusted syngas stream from step D1) and / or at least a portion of the second adjusted syngas stream from steps D2) or D3) to a rWGS reaction. In one embodiment of the process of the presentBASF SE 240445W001- 18 - invention, especially in the case when methanol is prepared as downstream product from the syngas, no rWGS is carried out.Step E)Within the scope of this invention, the syngas obtained and provided according to steps A), B), C1) / C2), and D1) / D2) / D3), respectively, may be converted further to first downstream products, e.g., methanol, Fischer-Tropsch hydrocarbons, or methane, preferably, methanol is the first downstream product.For these different conversions, the H2-to-CO molar ratio in the syngas may need to be adjusted to different values, which can be achieved with the help of the water-gas shift reaction, admixture of hydrogen, and removal or addition of CO2, as known to the one of skill in the art and described herein.Methanol ProductionMethanol may be produced from syngas by a catalytic gas phase reaction in a low-pressure process at about 5-10 MPa and about 200-300 °C, e.g., in adiabatic reactors or quasi-isothermal reactors. The catalyst is for example a mixture of copper and zinc oxides on alumina support. Details on the methanol synthesis and various options thereof suitable to be combined with the processes described herein are disclosed, e.g., in Ott et al., Ullmann's Encyclopedia of Industrial Chemistry (2012), Chapter "Methanol”, p. 3 to 13.A process for the direct production of methanol (MeOH) from carbon dioxide (CO2) utilizes the catalytic hydrogenation of CO2 with hydrogen, without first converting it to carbon monoxide (CO). In this approach, CO2 is reacted with H2 under elevated pressure (typically 5-10 MPa) and moderate temperatures (typically 200-300 °C) in a reactor, preferably using a copper-zinc oxide catalyst on alumina (direct hydrogenation of CO2 to methanol). The chemical reaction can be described as follows:CO2 +3H2 CH3OH + H2OSuitable catalysts and process conditions are known in the art. In said process, CO2 is directly transformed into methanol and water. Preferably, at least a portion of the CO2 is obtained from step D1).Dimethyl ether (DME) may be formed from syngas via methanol by dehydration. When methanol production and dehydration are combined in one reactor, DME can also be produced directly from syngas.Fischer-Tropsch (FT) ProcessesFT synthesis refers to the catalytic process of manufacturing mainly liquid hydrocarbons from syngas. The produced hydrocarbons (also denoted "FT hydrocarbons”) comprise alkanes and alkenes and, depending on the process conditions (e.g., temperature and catalyst), range from substitute natural gas over gasoline (boiling range of approx. 50-180 °C) and diesel oil (boiling rage of approx. 180-320 °C) to waxes. Refining of this raw product spectrum delivers commercially attractive fractions like liquefied petroleum gases (LPG), gasoline, diesel fuels, or olefins for petrochemical use. Refining may include typical fractionation techniques to separate the obtained raw products like distillation as well as process steps to further modify the chemical composition of the obtained raw products, like cracking and isomerization, in particular hydrocracking and hydroisomerization, and combinations thereof.BASF SE 240445W001- 19 - Fischer-Tropsch (FT) processes may be carried out as low-temperature (LTFT) and high-temperature (HTFT) processes. In LTFT processes, e.g., carried out in tubular fixed-bed reactors or slurry bed reactors, typically temperatures of 220-250 °C, pressures of about 4.4 MPa, and iron- or cobalt-based catalysts are employed to obtain higher amounts of diesel and wax fractions. In HTFT processes, e.g., carried out in circulating fluidized-bed reactors and SAS (Sasol advanced synthol) reactors, typically temperatures of 330-350 °C, pressures of about 2.5 MPa and iron-based catalysts are used to increase the yields of light olefin and gasoline fractions. Also, ruthenium-based catalysts have proven to be active in FT processes.Details on FT products and FT processes are disclosed for example in T. Kaneko et al., Ullmann's Encyclopedia of Industrial Chemistry, 2012, Chapter "Coal Liquefaction”, A. Yu. Krylova, Solid Fuel Chemistry 2014, 48, 22-35, T. Lin et al, ACS Catal. 2022, 12, 12092-12112, and the references cited therein.MethanationSyngas can be converted to methane in a methanation reaction. The methanation reaction is described by chemical reaction schemes (1) and (2):CO + 3H2 -> CH4 + H2O (1)CO2 +4H2 -> CH4 +2 H2O (2)The methanation reaction is for example a catalytic reaction using nickel on alumina catalysts, preferably a honeycomb shape catalyst, at 1 to 70 bar and 200 to 700 °C, preferably 5 to 60 bar, more preferably 10 to 45 bar and preferably 200 to 550 °C.The methanation reaction is described, e.g., in Rbnsch et al., Fuel 2016, 166, 276-296.Preferred Embodiments1.35) A process to produce at least one first downstream product selected from the group consisting of methanol, dimethyl ether, FT hydrocarbons, and methane, preferably methanol, the process comprising the process to produce syngas according to any of the preceding embodiments and further comprising step E)E) converting at least a portion of the first adjusted syngas stream from step D1) and / or at least a portion of the second adjusted syngas stream from steps D2) or D3) to obtain said at least one first downstream product. 1.36) The process according to any of the preceding embodiments, wherein in step E), said downstream product is methanol and said conversion is carried out in the presence of a catalyst at about 5-10 MPa and about 200- 300 °C.1.37) The process according to any of the preceding embodiments, wherein in step E), said downstream product is a FT hydrocarbon and said conversion is carried out in the presence of an iron- or cobalt-based catalyst at about 220-250 °C and optionally comprises one or more process steps selected from the group consisting of fractionation, distillation, cracking and isomerization.1.38) The process according to any of the preceding embodiments, wherein in step E), said downstream product is a FT hydrocarbon and said conversion is carried out in the presence of an iron- or ruthenium-based catalyst at about 330-350 °C and optionally comprises one or more process steps selected from the group consisting of fractionation, distillation, cracking and isomerization.BASF SE 240445W001- 20 - 1.39) The process according to any of the preceding embodiments, wherein in step E), said downstream product is methane and said conversion is carried out in the presence of a nickel-based catalyst at about 10-45 bar and about 200-550 °C.Step F)Within the scope of this invention, additional process steps may follow to yield further downstream products which means chemicals, chemical materials, related products, monomers, polymers, and polymer products manufactured in successive processing from the syngas obtained in steps D 1 ) / D2) / D3) and / or the first downstream products obtained in step E).In particular, a process step may be comprised for converting the syngas and / or the first downstream products obtainable by or obtained by the process as described herein to obtain a chemical material, monomer, polymer, or polymer product.The publication Prior Art Disclosure; Issue 684; paragraphs

[1000] to

[8005] ; ISSN: 2198-4786; published: February 12, 2024, will be regarded as Reference RF1, which is incorporated herein by reference in its entirety. Preferably, the downstream product PRF1 is a product as described in Reference RF1; paragraphs

[1000] to

[8005] , Preferably, the process described herein is further a process for the production of a downstream product, preferably product PRF1. The converting step to obtain the product PRF1 preferably comprises one or more step(s) as described below and can be performed by conventional methods well known to a person skilled in the art. The converting step preferably comprises one or more step(s) selected from:recycling, preferably depolymerizing, gasifying, pyrolyzing, and / or steam cracking; and / orpurifying, preferably crystallizing, (solvent) extracting, distilling, evaporating, hydrotreating, absorbing, adsorbing and / or subjecting to ion exchanger; and / orassembling, preferably foaming, synthesizing, chemical conversion, chemically transforming, polymerizing and / or compounding; and / orforming, preferably foaming, extruding and / or molding; and / orfinishing, preferably coating and / or smoothing.In addition, the one or more step(s) are described in detail in Reference RF1; paragraphs

[1000] to

[8005] ,The term "building block”, as used herein, comprises compounds, which are in a gaseous or liquid state under standard conditions of 0 °C and 0.1 MPa. Building blocks are typically used in chemical industry to form secondary products, which provide a higher structural complexity and / or higher molecular weight than the building block on which the secondary product is based. The building block is preferably selected from the group consisting of hydrogen, carbon monoxide, carbon dioxide, ethylene oxide, ethylene glycols, syngas comprising a mixture of hydrogen and carbon monoxide, alkanes, alkenes, alkynes and aromatic compounds. The alkanes, alkenes, alkynes and aromatic compounds comprise in particular 1 to 12 carbon atoms, respectively.The term "monomer”, as used herein, comprises molecules, which can react with each other to form polymer chains by polymerization. The monomer is preferably selected from the group consisting of (meth)acrylic acid, salts of (meth)acrylic acid; in particular sodium, potassium and zinc salts; (meth)acrolein and (meth)acrylates. (Meth)acrylates comprising 1 to 22 carbon atoms are preferred, in particular comprising 1 to 8 carbon atoms. The terms (meth)acrylicBASF SE 240445W001- 21 -acid, (meth)acrolein or (meth)acrylate relate to acrylic acid, acrolein or acrylate and also to methacrylic acid, methacrolein or methacrylate, where applicable. Further, the monomer can be selected from hexamethylenediamine (HMD) and adipic acid.The building block can further be an intermediate compound. The term "intermediate compound”, as used herein, comprises organic reagents, which are applied for formation of compounds with higher molecular complexity. The intermediate compound can be selected for example from the group consisting of phosgene, polyisocyanates and propylene oxide. The polyisocyanates are in particular aromatic di- and polyisocyanates, preferably toluene diisocyanate (TDI) and / or diphenylmethane diisocyanate (methylene diphenyl diisocyanate; MDI).The building block and the monomer and typical converting step(s) to obtain the building block or monomer are described in more detail in paragraphs

[1000] to

[1012] of Reference RF1.The term "polymer A”, as used herein, comprises thermoplastic, e.g., polyamide or thermoplastic polyurethane, thermoset, e.g., polyurethane, elastomer, e.g., polybutadiene, or a copolymer or a mixture thereof and is defined in more detail in paragraphs

[2001] to

[2007] of Reference RF1.The term "polymer composition A”, as used herein, comprises all compositions comprising a polymer as described above and one or more additive(s), e.g. reinforcement, colorant, modifier and / or flame retardant, and is defined in more detail in paragraph

[2008] of Reference RF1.The term "polymer product A”, as used herein, comprises any product comprising the polymer A and / or polymer composition A as described above and is defined in more detail in paragraphs

[2009] and

[2010] of Reference RF1. The step(s) to obtain the polymer, preferably polymer A, polymer composition, preferably polymer composition A or polymer product, preferably polymer product A is / are described in more detail in paragraph

[2011] of Reference RF1. The term "industrial use polymer”, as used herein, comprises rheology, polycarboxylate, alkoxylated polyalkylenamine, alkoxylated polyalkylenimine, polyether-based, dye inhibition and soil release cleaning polymers defined in more detail in paragraphs

[3035] to

[3044] of Reference RF1. The term "industrial use surfactant”, as used herein, comprises nonionic, anionic and amphoteric industrial use surfactants defined in more detail in paragraphs

[3008] to

[3034] of Reference RF1. The term "industrial use descaling compound”, as used herein, comprises non-phosphate based builders (NPB) and phosphonates (CoP) described in more detail in paragraphs

[3001] to

[3005] of Reference RF1. The term "industrial use biocide”, as used herein, refers to a chemical compound that kills microorganisms or inhibits their growth or reproduction defined in more detail in paragraphs

[3006] to

[3007] of Reference RF1. The term "industrial use solvent”, as used herein, comprises alkyl amides, alkyl lactamides, alkyl esters, lactate esters, alkyl diester, cyclic alkyl diester, cyclic carbonates, aromatic aldehydes and aromatic esters defined in more detail in paragraphs

[3045] to

[3055] of Reference RF1. The term "industrial use dispersant”, as used herein, comprises anionic and non-ionic industrial use dispersants defined in more detail in paragraphs

[3056] to

[3058] of Reference RF1. The term "composition and / or formulation thereof” with reference to the industrial use polymers, industrial use surfactants, descaling compounds and / or industrial use biocides refers to industrial use compositions and / or institutional use products and / or fabric and home care products and / or personal care products defined in more detail in paragraph

[3059] of Reference RF1. The converting step(s) to obtain the industrial use polymer, industrial use surfactant, descaling compound and / or industrial use biocide are defined in more detail in paragraph

[3060] of Reference RF1. The converting steps to obtainBASF SE 240445W001- 22 -the industrial use composition or formulation of the industrial use polymer, industrial use surfactant, descaling compound and / or industrial use biocide are defined in more detail in paragraph

[3061] of Reference RF1.The term "agrochemical composition”, as used herein, typically relates to a composition comprising an agrochemically active ingredient and at least one agrochemical formulation auxiliary. Examples of agrochemical compositions, active ingredients and auxiliaries are described in more detail in Reference RF1, paragraph

[4001] ,The agrochemical composition may take the form of any customary formulation. The agrochemical compositions are prepared in a known manner, e.g. described by Mollet and Grubemann, Formulation technology, Wiley VCH, Weinheim, 2001; or Knowles, New developments in crop protection product formulation, Agrow Reports DS243, T&F Informa, London, 2005. The converting step(s) to obtain the agrochemically active ingredients and auxiliaries may be conducted in analogy to the production step(s) of their analogues that are based on petrochemicals or other precursors that are not gained by recycling processes. In addition, conversion to compounds mentioned in sections "Polymer” and "Cosmetic surfactant, emollient, wax, cosmetic polymer, UV filter, further cosmetic ingredient or compositions or formulations thereof' may be performed as described in these sections as well as the respective paragraphs in Reference RF1.The term active pharmaceutical ingredients and / or intermediates thereof, as used herein, comprises substances that provide pharmacological activity or other direct effect in the diagnosis, cure, mitigation, treatment, or prevention of disease, or to affect the structure or any function of the body. Intermediates thereof are isolated products that are generated during a multi-step route of synthesis of an active pharmaceutical ingredient. The term pharmaceutical excipients, as used herein, comprises compounds or compound mixtures used in compositions for various pharmaceutical applications, which are not substantially pharmaceutically active on itself. Active pharmaceutical ingredients and / or intermediates thereof and pharmaceutical excipients are defined in more detail in paragraph

[5001] of Reference RF1. The converting step(s) to obtain the active pharmaceutical ingredients and / or intermediates thereof and pharmaceutical excipients may comprise one or more synthesis steps and can be performed by conventional synthesis and techniques well known to a person skilled in the art.The terms animal feed additives, human food additives, dietary supplements, as used herein, comprises Vitamins, Pro-Vitamins and active metabolites thereof including intermediates and precursors, especially Vitamin A, B, E, D, K and esters thereof, like acetate, propionate, palmitate esters or alcohols thereof like retinol or salts thereof and any combinations thereof; Tetraterpenes, especially isoprenoids like carotenoids and xanthophylls including their intermediates and precursors as well as mixtures and derivates thereof, especially beta carotene, Canthaxanthin, Citranaxanthin, Astaxanthin, Zeaxanthin, Lutein, Lycopene, Apo-carotenoids, and any combinations thereof; organic acids, especially formic acid, propionic acid and salts thereof, such as sodium, calcium or ammonium salts, and any combinations thereof, such as but not limited to mixtures of formic acid and sodium formiate, propionic acid and ammonium propionate, formic acid and propionic acid, formic acid and sodium formiate and propionic acid, propionic acid and sodium propionate and formic acid and sodium formiate; glycerides of carboxylic acids and short and medium chain fatty acids, conjugated linoleic acids, such as omega-6 fatty acid (C18:2) methyl ester and 1 ,2-propandiol and beverage stabilizers, such as polyvinylpyrrolidone-polymer or polyvinylimidazole / polyvinylpyrrolidone-copolymer. Animal feed additives, human food additives and dietary supplements are defined in more detail in paragraph

[5002] of Reference RF1.BASF SE 240445W001- 23 - The converting step(s) to obtain the animal feed additives, human food additives, dietary supplements may comprise one or more synthesis steps and can be performed by conventional synthesis and techniques well known to a person skilled in the art.The terms aroma chemical and aroma composition as used herein, comprise a volatile organic substance with a molecular weight between 70-250 g / mol comprising a functional group with a carbon skeleton of C5-C16 carbon atoms comprising linear, branched, cyclic, for example with a ring size of C5-C18, bicyclic or tricyclic aliphatic chains and but not necessarily one or more unsaturated structural elements like double bonds, triple bonds, aromatics or heteroaromatics and preferably the one or more additional functional groups are selected from alcohol, ether, ester, ketone, aldehyde, acetal, carboxylic acid, nitrile, thiol, amine. In one aspect, the aroma chemical is a terpene-based aroma chemical, for example selected from monoterpenes and monoterpenoids, sesquiterpenes and sesquiterpenoids, diterpenes, triterpenes or tetraterpenes. Aroma chemicals can be combined with further aroma chemicals to give an aroma composition. Aroma chemicals and aroma compositions are defined in more detail in paragraph

[5003] of Reference RF1.The converting step(s) to obtain the aroma chemical and aroma composition may comprise one or more synthesis steps and can be performed by conventional synthesis and techniques well known to a person skilled in the art. The term "aqueous polymer dispersion”, as used herein, comprises aqueous composition(s) comprising dispersed polymer(s) and is defined in more detail in the section

[6001] entitled "aqueous polymer dispersion” of Reference RF1. The dispersed polymer(s) may be selected from acrylic emulsion polymer(s), styrene acrylic emulsion polymer(s), styrene butadiene dispersion(s), aqueous dispersion(s) comprising composite particles, acrylate alkyd hybrid disper-sion(s), polyurethane(s) (including UV-curable polyurethanes) and polyurethane - poly(meth)acrylate hybrid poly-mer(s). The term "emulsion polymer”, as used herein, comprises polymer(s) made by free-radical emulsion polymerization. Aqueous polyurethane dispersion(s) are defined in more detail in the section

[6002] entitled "Polyurethane dispersions” of Reference RF1. UV-curable polyurethane(s) is / are defined in more detail in the section

[6017] of Reference RF1. Polyurethane - poly(meth)acrylate hybrid polymer(s) is / are defined in more detail in the section

[6016] of Reference RF1.The term "polymeric dispersant”, as used herein, comprises preferably polymer(s) comprising polyether side chain, in particular polycarboxylate ether polymer(s) and polycondensation product(s) defined in more detail in paragraph

[6020] entitled "Polymeric dispersant” of Reference RF1.The converting (polymerization) step(s) to obtain the aqueous polymer dispersion(s) comprising emulsion polymer(s) is / are defined in more detail in the section

[6003] entitled "Emulsion polymerization” of Reference RF1.The converting (polymerization) step(s) to obtain the aqueous polyurethane dispersion(s) is / are defined in more detail in the section

[6014] entitled "Process for the preparation of aqueous polyurethane dispersions” and section

[6017] entitled "Aqueous UV-curable polyurethane dispersions, their preparation and use and compositions containing them” of Reference RF1.Composition(s) and uses of aqueous polymer dispersion(s) and of polymeric dispersant(s) are defined in more detail in the following sections of Reference RF1:section

[6004] entitled "Uses of aqueous polymer dispersions”,section

[6005] entitled "Binders for architectural and construction coatings”BASF SE 240445W001- 24 -section

[6006] entitled "Binders for paper coating”section

[6007] entitled "Binders for fiber bonding”section

[6008] entitled "Adhesive polymers and adhesive compositions”section

[6015] entitled "Aqueous polyurethane dispersions suitable for use in coating compositions”section

[6016] entitled "Aqueous polyurethane - poly(meth)acrylate hybride polymer dispersions suitable for use in coating compositions”section

[6017] entitled "Aqueous UV-curable polyurethane dispersions, their preparation and use and compositions containing them”section

[6018] entitled "Inorganic binder compositions comprising polymeric dispersants and their use”

[6019] 100% curable coating compositionsUV-crosslinkable poly(meth)acrylate(s) and its / their uses are defined in more detail in section

[6009] entitled "UV-crossli nkable poly(meth)acrylates for use in UV-curable solvent-free hotmelt adhesives and their use for making pressure-sensitive self-adhesive articles” of Reference RF1.Polyisocyanate(s), composition(s) comprising them and their uses are defined in more detail in section

[6010] entitled "Polyisocyanates” of Reference RF1.Hyperbranched polyester polyol(s) and its / their uses are defined in more detail in section

[6011] entitled "Organic solvent based hyperbranched polyester polyols suitable for use in coating compositions” of Reference RF1. The converting step(s) to obtain the hyperbranched polyester polyols is / are defined in more detail in the section

[6012] entitled "Preparation of organic solvent based hyperbranched polyester polyols” of Reference RF1. Coating composition(s) comprising hyperbranched polyester polyol(s), polyisocyanate(s) and additive(s) and substrate(s) coated therewith are defined in more detail in section

[6013] entitled "Organic solvent based two component coating compositions comprising hyperbranched polyester polyols and polyisocyanates” of Reference RF1.Unsaturated polyester polyol(s), solvent-based coating composition(s) comprising said unsaturated polyester polyol(s) and substrate(s) for coating with said coating composition(s) are defined in more detail in section

[6018] entitled "Organic solvent based coating composition comprising unsaturated polyester polyols” of Reference RF1.100% curable coating composition(s) is / are defined in more detail in section

[6019] of Reference RF1.Polymeric dispersant(s) for inorganic binder compositions is / are defined in more detail in section

[6020] of Reference RF1. The inorganic binder composition (s) comprising the polymeric dispersants and their use are defined in more detail in section

[6021] of Reference RF1. The converting step(s) to obtain the polymeric dispersant(s) are defined in more detail in section

[6020] of Reference RF1. The term "inorganic binder composition” comprising the polymeric disper-sant(s), as used herein, comprises preferably in particular hydraulically setting compositions and compositions comprising calcium sulfate and is defined in more detail in section

[6021] of Reference RF1 entitled "Inorganic binder compositions comprising the polymeric dispersant and their use”. Specific building material formulation(s) comprising polymeric dispersant(s) or building product(s) produced by a building material formulation comprising a polymeric dispersant are disclosed in more detail in section

[6021] of Reference RF1.The term "cosmetic surfactant”, as used herein, comprises non-ionic, anionic, cationic and amphoteric surfactants and is defined in more detail in paragraph

[7002] of Reference RF1. The term "emollient”, as used herein, refers to a chemical compound used for protecting, moisturizing, and / or lubricating the skin and is defined in more detail inBASF SE 240445W001- 25 -paragraph

[7003] of Reference RF1. The term "wax”, as used herein, comprises pearlizers and opacifiers and is defined in more detail in paragraph

[7004] of Reference RF1. The term "cosmetic polymer”, as used herein, comprises any polymer that can be used as an ingredient in a cosmetic formulation and is defined in more detail in paragraph

[7005] of Reference RF1. The term "UV filter”, as used herein, refers to a chemical compound that blocks or absorbs ultraviolet light and is defined in more detail in paragraph

[7006] of Reference RF1. The term "further cosmetic ingredient”, as used herein, comprises any ingredient suitable for making a cosmetic formulation. Several sources disclose cosmetically acceptable ingredients. E. g. the database Cosing on the internet pages of the European Commission discloses cosmetic ingredients and the International Cosmetic Ingredient Dictionary and Handbook, edited by the Personal Care Products Council (PCPC), discloses cosmetic ingredients. The term "composition and / or formulation thereof” with reference to the cosmetic surfactant, emollient, wax, cosmetic polymer, UV filter and / or further cosmetic ingredient refers to personal care and / or cosmetic compositions or formulations defined in more detail in paragraph

[7007] of Reference RF1. The converting step(s) to obtain the cosmetic surfactant, emollient, wax, cosmetic polymer, UV filter or further cosmetic ingredient is / are defined in more detail in paragraph

[7008] of Reference RF1.The terms "polymer B”, "polymer composition B”, "coating composition”, "other functional composition”, "foil”, "molded body”, "coating” and "coated substrate” are well known to the person skilled in the art and are defined in more detail from paragraph

[8000] to

[8005] of Reference RF1.Preferred embodiments1.40) A process to produce at least one downstream product, preferably at least one product PRF1, the process comprising the process according to any of the preceding embodiments and further comprising step F) F) converting at least a portion of the first adjusted syngas stream from step D1) and / or at least a portion of the second adjusted syngas stream from steps D2) or D3) and / or at least a portion of the first downstream product from step E) to obtain at least one downstream product.1.41) The process according to embodiment 1.40, wherein the product PRF1 is selected from:I) building block or monomer; orii) polymer, preferably polymer A, polymer composition, preferably polymer composition A, or polymer product, preferably polymer product A; orill) cleaning polymer, cleaning surfactant, descaling compound, cleaning biocide or composition or formulation thereof; oriv) agrochemical composition, agrochemical formulation auxiliary or agrochemically active ingredient; or v) active pharmaceutical ingredient or intermediate thereof, pharmaceutical excipient, animal feed additive, human food additive, dietary supplements, aroma chemical or aroma composition; orvi) aqueous polymer dispersion, preferably polyurethane or polyurethane - poly (meth)acrylate hybrid polymer dispersion, emulsion, binder for paper and fiber coatings, UV-curable acrylic polymer for hot melts and coatings polyisocyanates, hyperbranched polyester polyol, polymeric dispersant for inorganic binder compositions, unsaturated polyester polyol or 100% curable composition; orvii) cosmetic surfactant, emollient, wax, cosmetic polymer, UV filter, further cosmetic ingredient or composition or formulation thereof; orBASF SE 240445W001- 26 - viii) polymer B, polymer composition B, coating composition, other functional composition, foil, molded body, coating or coated substrate.1.42) The process according to any one of embodiments 1.40 to 1.41 ,wherein the content of said syngas and / or of said first downstream product in the product PRF1 is 1 weight-% or more, preferably 2 weight-% or more, more preferably 5 weight-% or more, more preferably 15 weight-% or more, more preferably 30 weight-% or more, more preferably 40 weight-% or more, more preferably 60 weight-% or more, more preferably 80 weight-% or more, more preferably 90 weight-% or more, more preferably 95 weight-% or more; and / orwherein the content of said syngas and / or of said first downstream product in the product PRF1 is 100 weight.% or less, preferably 95 weight-% or less, more preferably 90 weight-% or less, more preferably 50 weight- % or less, more preferably 25 weight-% or less, more preferably 10 weight-% or less; andpreferably wherein the content is determined based on identity preservation and / or segregation and / or mass balance and / or book and claim chain of custody models, preferably based on mass balance, preferably the International Sustainability and Carbon Certification (ISCC) standard.Further embodiments of the first aspect of the invention are described by the combination of any and each of the above definitions and embodiments with one another, in particular by way of FIGs 1-3:FIG 1 depicts a first mode of a process for the production of a downstream product (6) of syngas: The feedstock (1), preferably of biobased or recycling-based origin, is gasified (11) in the presence of oxygen (9) to obtain a raw syngas (2). The raw syngas (2) is subjected to a WGS reaction (12) such that H2-enriched syngas (3a) is formed. Carbon dioxide (4) is captured (13) from (3a) and stored (14). The adjusted syngas (5) is finally converted (15) to a first downstream product (6), in particular methanol. The degrees of H2 enrichment via WGS reaction (12) and CO2 depletion (13) are chosen such that a composition of the adjusted syngas (5) is achieved that meets the stoichiometric requirements of the downstream conversion process (15). This first process mode may be run, for instance, when there is no renewable energy available to produce green hydrogen via water electrolysis, e.g., as a "night mode”.FIG 2 depicts a second mode of a process for the production of a downstream product (6) of syngas: The feedstock (1), preferably of biobased or recycling-based origin, is gasified (11) in the presence of oxygen (9) to obtain a raw syngas (2). Said oxygen (9) is preferably provided from electrolysis (16) of water (7) driven by renewable energies, in particular solar power. Also, water electrolysis (16) delivers hydrogen (8) that may be admixed to the raw syngas (2); further, CO2 (4) is added to (2) to obtain adjusted syngas (5), preferably said CO2 (4) originates from the first process mode described hereinbefore, e.g., in the context of FIG 1. In a final step, (5) is converted (15) to a first downstream product (6), in particular methanol. The degrees of H2 and CO2 admixture are chosen such that a composition of the adjusted syngas (5) is achieved that meets the stoichiometric requirements of the downstream conversion process (15). This second process mode may be run, for instance, when there is enough renewable energy available to produce green hydrogen (8) via water electrolysis (16), e.g., as a "day mode”.BASF SE 240445W001- 27 - FIG 3 depicts the dual-mode process for the production of a downstream product (6) of syngas: FIG 3 is a combined illustration of the first and second process modes described by FIGs 1 and 2. The dual-mode process is equipped and configured to switch between these two modes. Also, it is conceived that parts of both modes may be run concurrently ("simultaneous mode”), e.g., the WGS reaction (12), CO2 capture (13) and storage (14) may be combined with water electrolysis (16) and H2 (8) admixture to obtain adjusted syngas (5); likewise, the WGS reaction (12) may be combined with water electrolysis (16), H2 (8) and CO2 (4) admixture to obtain adjusted syngas (5).The different embodiments described herein for the first aspect of the invention apply equally to the further aspects of the invention.Thus, in a second aspect, the invention relates to a system for producing syngas, the system comprising the units I) gasification unit;II) water-gas shift unit;III) CO2 capture unit;IV) CO2 storage unit;V) water electrolysis unit; andVI) mixing unit.As used herein, the term system refers to an arrangement of units that allows for the exchange of material and / or energy streams between the different units. Said exchange may be accomplished by fluid connections, by pipelines, or by other means of transportation. In particular, said system may be embodied by a production plant, more specifically by an integrated production plant, e.g., by a flexible manufacturing system.Preferred Embodiments2.1) The system according to the second aspect of the invention.2.2) The system according to any of the preceding embodiments, wherein the system is a production plant, preferably an integrated production plant.2.3) The system according to any of the preceding embodiments, wherein the system is a flexible manufacturing system.The sets of preferred embodiments described in the following for the different system units are intended to further illustrate, but in no way to restrict the present invention as described herein. They represent a suitably structured part of the description and thus support, but do not represent the claims of the present invention.BASF SE 240445W001- 28 - Unit I)The gasification unit I) is equipped to perform process step B) as described above, including its different embodiments. In particular, it is equipped to receive, store, and pre-treat a gasification feedstock stream, to produce raw syngas therefrom, to purify it, and to provide it to a WGS unit II) and / or a mixing unit VI).The gasification unit I) may thus comprise a pre-treatment subunit that is fed with the feedstock for gasification and is equipped to pre-treat said feedstock as described for step B) above.The gasification unit I) may further comprise a purification subunit that is equipped to purify the raw syngas as described for step B) above.Preferred Embodiments2.4) The system according to any of the preceding embodiments, wherein unit I) is fluidly connected and arranged upstream to unit II).2.5) The system according to any of the preceding embodiments, wherein unit I) is fluidly connected and arranged upstream to unit VI).2.6) The system according to any of the preceding embodiments, wherein unit I) is fluidly connected and arranged downstream to unit V).2.7) The system according to any of the preceding embodiments, wherein unit I) comprises a pre-treatment subunit.2.8) The system according to any of the preceding embodiments, wherein unit I) comprises a purification subunit.Unit II)The water-gas shift unit II) is equipped to perform process step C1) as described above, including its different embodiments. In particular, it is equipped to receive raw syngas from unit I), to produce H2-enriched syngas therefrom, and to provide it to the CO2 capture unit III) and / or to the mixing unit VI).Preferred Embodiments2.9) The system according to any of the preceding embodiments, wherein unit II) is fluidly connected and arranged downstream to unit I).2.10) The system according to any of the preceding embodiments, wherein unit II) is fluidly connected and arranged upstream to unit III).2.11) The system according to any of the preceding embodiments, wherein unit II) is fluidly connected and arranged upstream to unit VI).Unit ill)The CO2 capture unit III) is equipped to perform the CO2 separation from syngas according to process step D1) as described above, including its different embodiments. In particular, it is equipped to receive H2-enriched syngas from unit II), to separate CO2 therefrom, optionally to provide CO2-depleted syngas to the mixing unit VI) and adjusted syngas to the downstream conversion unit VII), respectively, and CO2 to the CO2 storage unit IV).BASF SE 240445W001- 29 - Preferred Embodiments2.12) The system according to any of the preceding embodiments, wherein unit III) is fluidly connected and arranged downstream to unit II).2.13) The system according to any of the preceding embodiments, wherein unit III) is fluidly connected and arranged upstream to unit VI).2.14) The system according to any of the preceding embodiments, wherein unit III) is fluidly connected and arranged upstream to unit VII).2.15) The system according to any of the preceding embodiments, wherein unit III) is fluidly connected and arranged upstream to unit IV).2.16) The system according to any of the preceding embodiments, wherein unit III) comprises at least one subunit selected from the group consisting of a membrane separation subunit, a cryogenic separation subunit, an absorption subunit, and an adsorption subunit.Unit IV)The CO2 storage unit IV) is equipped to perform the CO2 storage according to process step D1) as described above, including its different embodiments. In particular, it is equipped to receive CO2 from unit III), optionally to purify and / or to dry it, to liquefy it, to store it, and to provide it to the mixing unit VI).Preferred Embodiments2.17) The system according to any of the preceding embodiments, wherein unit IV) is fluidly connected and arranged downstream to unit III).2.18) The system according to any of the preceding embodiments, wherein unit IV) is fluidly connected and arranged upstream to unit VI).2.19) The system according to any of the preceding embodiments, wherein unit IV) comprises a CO2 purification subunit and / or a CO2 drying subunit.2.20) The system according to any of the preceding embodiments, wherein unit IV) comprises a CO2 liquefaction subunit.The water electrolysis unit V) is equipped to perform process step C2) as described above, including its different embodiments. In particular, it is equipped to receive and store water, optionally to purify it, and to electrolyze it to hydrogen and oxygen. Unit V) is equipped to provide hydrogen to the mixing unit VI) and optionally to provide oxygen to the gasification unit I).Preferred Embodiments2.21) The system according to any of the preceding embodiments, wherein unit V) is fluidly connected and arranged upstream to unit VI).BASF SE 240445W001- 30 - 2.22) The system according to any of the preceding embodiments, wherein unit V) is fluidly connected and arranged upstream to unit I).Unit VI)The mixing unit VI) is equipped to perform process steps D2) and D3) as described above, including its different embodiments. In particular, it is equipped to receive raw syngas from unit I) and / or CO2-depleted syngas from unit III) as well as CO2 from unit IV) and hydrogen from unit V) and to mix these different streams in defined ratios to deliver an adjusted syngas stream that meets the stoichiometric requirements of downstream processes.Preferred Embodiments2.23) The system according to any of the preceding embodiments, wherein unit VI) is fluidly connected and arranged downstream to units I) and III).2.24) The system according to any of the preceding embodiments, wherein unit VI) is fluidly connected and arranged downstream to unit II).2.25) The system according to any of the preceding embodiments, wherein unit VI) is fluidly connected and arranged downstream to unit V).2.26) The system according to any of the preceding embodiments, wherein unit VI) is fluidly connected and arranged downstream to unit IV).2.27) The system according to any of the preceding embodiments, wherein unit VI) is fluidly connected and arranged upstream to unit VII).Further unitsThe system according to the invention may comprise further units and subunits, e.g., for performing the further process steps described above, like purification and separation steps or the rWGS reaction.In one embodiment of the system of the present invention, especially in the case when methanol conversion unit is present as a downstream conversion unit, no rWGS unit is present.Unit VII) downstream conversion unitThe downstream conversion unit VII) is equipped to perform process steps E) and / or F) as described above, including their different embodiments. In particular, it is equipped to receive an adjusted syngas stream from the CO2 capture unit III) and / or from the mixing unit VI) and to convert it to a first or further downstream product.Preferred Embodiments2.28) A system for producing at least one downstream product, the system comprising the system for producing syngas according to any of the preceding embodiments and further comprising unit VII)VII) downstream conversion unit.2.29) The system according to embodiment 2.28, wherein unit VII) is fluidly connected and arranged downstream to unit ill).BASF SE 240445W001- 31 - 2.30) The system according to any of embodiments 2.28 to 2.29, wherein unit VII) is fluidly connected and arranged downstream to unit III).2.31) The system according to any of embodiments 2.28 to 2.30, wherein unit VII) is fluidly connected and arranged downstream to unit VI).Further embodiments of the second aspect of the invention are described by the combination of any and each of the above definitions and embodiments with one another, in particular by way of FIG 4.FIG 4 depicts a system for performing the processes according to FIGs 1-3: A gasification unit (101) receives gasification feedstock (1) and optionally oxygen (9) from a water electrolysis unit (107) which is fed with water (7). The gasification unit (101) may deliver raw syngas (2) to the WGS unit (102) and / or to the mixing unit (105). The WGS unit (102) provides H2-enriched syngas (3a) to the CO2 capture unit (103) and / or to the mixing unit (105). The CO2 capture unit (103) forwards CO2 (4) to the CO2 storage unit (104) and / or CO2-depleted syngas (3b) to the mixing unit (105) and / or adjusted syngas (5) to the downstream conversion unit (106). The CO2 capture unit (104) may provide CO2 (4) to the mixing unit (105). The mixing unit (105) may receive the above-mentioned streams (2, 3a, 3b, 4) as well as hydrogen (8) from the water electrolysis unit (107). The mixing unit (105) provides adjusted syngas (5) to the downstream conversion unit (106). The downstream conversion unit (106) outputs at least one downstream product (6).The different embodiments described herein for the second aspect of the invention apply equally to the further aspects of the invention, in particular to the third aspect of the invention.In a third aspect, the invention relates to a process to operate a system for producing syngas, said process comprising the steps51 ) operating the system in a first operation mode for a first period of time;52) switching the operation mode at the end of said first period of time from said first operation mode to a second operation mode, wherein said second operation mode is not identical to said first operation mode;53) operating the system in a second operation mode for a second period of time;54) switching the operation mode at the end of said second period of time from said second operation mode back to said first operation mode.The embodiments described for the first and second aspect of the invention, relating to operation modes, process steps, systems, units, and subunits, apply equally to the third aspect of the invention.The sets of preferred embodiments described in the following are intended to further illustrate, but in no way to restrict the present invention as described herein. They represent a suitably structured part of the description and thus support, but do not represent the claims of the present invention.Preferred Embodiments3.1) The process according to the third aspect of the invention.BASF SE 240445W001- 32 - 3.2) The process according to any of the preceding embodiments, wherein said operation modes are operation modes according to any of the embodiments of the first aspect of the invention.3.3) The process according to any of the preceding embodiments, wherein said system for producing syngas is a system according to any of the embodiments of the second aspect of the invention.3.4) The process according to any of the preceding embodiments, wherein said first period of time is different from said second period of time.3.5) The process according to any of the preceding embodiments, wherein at least one, preferably both, of said first and second periods of time are less than 20 hours.3.6) The process according to any of the preceding embodiments, wherein the end of said first period of time and / or the end of said second period of time are determined according to a pre-defined schedule.3.7) The process according to any of the preceding embodiments, wherein the end of said first period of time and / or the end of said second period of time are determined by monitoring of external factors relevant for the provision of renewable energies.3.8) The process according to any of the preceding embodiments, wherein the quantitative syngas output per unit of time during said second period of time is approximately the same as the quantitative syngas output per unit of time during said first period of time.3.9) The process according to any of embodiments 3.1 to 3.7, wherein the quantitative syngas output per unit of time during said second period of time is higher than the quantitative syngas output per unit of time during said first period of time.In further aspects, the invention relates to the products obtained by carrying out the processes described herein, in particular to first downstream products like methanol, dimethyl ether, FT hydrocarbons, and methane and as well as to any fractions and downstream products thereof like monomers, polymers, or polymer products.ExamplesThe following examples are for the purpose of illustration of the invention only and are not intended in any way to limit the scope of the present invention.1) Biomass GasificationA typical elemental composition of biomass for gasification comprises the following molar fractions of H, C, and 0 (in relation to the total molar amount of H+C+O): 47 % H, 32% C, 21 % 0This translates into the following mass fractions (in relation to the total mass of H+C+O): 6 % H, 50 % C, 44 % 0 Gasification of such a biomass feedstock could be expected to deliver syngas of the following approximate composition (molar fractions): 40 % H2, 40 % CO, 20 % CO2Accordingly, a stoichiometric number (H2-CO2) / (CO+CO2) of 0.33 would be obtained, which is far below the value (namely 2.1) that is required for methanol synthesis from such syngas. Thus, there is an urgent need to increase theBASF SE 240445W001- 33 -stoichiometric number, e.g., via WGS reaction and subsequent CO2 removal or via H2 admixture, to enable efficient syngas conversion to methanol or other downstream products like FT hydrocarbons or methane.2) Methanol Synthesis in First Mode67.7 t / h of dry biomass are converted at full gasifier capacity to 55.0 t / h of dry raw syngas (H2-to-CO molar ratio of 1:1). 11.0 t / h of steam are added for the WGS reaction to deliver 39.1 t / h of syngas with a H2-to-CO molar ratio of 2: 1.26.8 t / h of CO2 are formed and separated for storage. Methanol synthesis from the 2:1 syngas delivers 37.5 t / h of methanol.3) Methanol Synthesis in Second Mode33.9 t / h of dry biomass are converted at half gasifier capacity to 27.5 t / h of dry raw syngas (H2-to-CO molar ratio of 1:1). Water electrolysis in a 200 MW electrolyzer delivers 3.7 t / h of H2 and 29.2 t / h of 02. The H2 along with 13.4 t / h of stored CO2 are admixed to the 1:1 syngas to obtain a combined syngas stream. Methanol synthesis from this combined syngas delivers 37.5 t / h of methanol. Optionally, the 29.2 t / h of 02 are used for the biomass gasification step.Of note, in this setup, the 002 consumption rate in second mode is approximately half the 002 buildup rate in the first mode (see Example 1). Accordingly, for complete use of the biomass feedstock in terms of carbon balance, the facility may operate in first mode for 1 / 3 of the time and in second mode for 2 / 3 of the time.4) Methanol Synthesis in Dual ModeThe process is run in dual mode wherein a first mode and a second mode are each run for 12 hours, assuming for the sake of example that the time from sunrise to sunset is approximately 12 hours, i.e., the process is run in a day-mode and in a night-mode.In the night-mode, biomass gasification and WGS reaction are operated at full capacity: 67.7 t / h of biomass are gasified along with 60.2 t / h of 02 to give 97.8 t / h of dried syngas. Complete WGS with 11.8 t / h of steam delivers 39.3 t / h of a syngas with a molar H2-to-CO ratio of 2:1. In addition, 70.3 t / h of CO2 are formed, captured, and stored. Said 2:1-syngas is converted to 37.5 t / h of methanol.In the day-mode, biomass gasification is run at 50% capacity: 33.8 t / h of dry biomass are gasified with 30.1 t / h of 02 to 48.9 t / h of dry raw syngas (H2-to-CO molar ratio of 1:1). Water electrolysis driven by solar energy in a 724 MW electrolyzer delivers 16.2 t / h of H2.

Claims

BASF SE 240445W001- 34 - Claims1. A process to produce syngas, wherein said process can operate in at least two distinct operation modes, wherein a first operation mode comprises the steps:A) providing at least one feedstock for gasification, the feedstock comprising biomass and / or waste;B) subjecting said feedstock to gasification to obtain raw syngas, comprising H2, CO, and CO2,01) subjecting said raw syngas to a water-gas shift reaction to obtain H2-enriched syngas; andD1) separating and storing at least a portion of the 002 comprised in said H2-enriched syngas to obtain a first adjusted syngas stream;andwherein a second operation mode comprises the steps A) and B), optionally comprises step 01), wherein the extent of the water-gas shift reaction is lower than in the first operation mode, and further comprises the steps: 02) carrying out water electrolysis, preferably using electrical power generated at least in part from non-fossil sources, to obtain hydrogen; andD2) admixing at least a portion of the hydrogen obtained in step 02) to the raw syngas obtained in step B) or to the H2-enriched syngas obtained in optional step 01) to obtain a second adjusted syngas stream;orwherein a second operation mode comprises the steps A) and B) and further comprises the steps:02) carrying out water electrolysis, preferably using electrical power generated at least in part from non-fossil sources, to obtain hydrogen; andD3) admixing at least a portion of the hydrogen obtained in step 02) and admixing additional 002, preferably at least a portion of the 002 from step D1), to the raw syngas obtained in step B) to obtain a second adjusted syngas stream.

2. The process according to any of the preceding claims,wherein the quantitative output per unit of time of said second adjusted syngas stream is approximately the same as the quantitative output per unit of time of said first adjusted syngas stream.

3. The process according to any of the preceding claims,wherein the amount of feedstock that is gasified in step B) in said first operation mode is higher than in said second operation mode.

4. The process according to any of the preceding claims,wherein the switches between said first operation mode and said second operation mode and vice versa are performed according to a monitoring of external factors relevant for the provision of renewable energies.

5. The process according to any of the preceding claims,wherein in step A) the combined mass fraction of biomass and waste in said at least one feedstock for gasificationBASF SE 240445W001- 35 - is more than 20 %, preferably more than 40 %, more preferably more than 50 %, more preferably more than 60 %, more preferably more than 70 %, more preferably more than 80 %, more preferably more than 90 %.

6. The process according to any of the preceding claims, wherein said process is carried out in a flexible manufacturing system.

7. The process according to claim 6,wherein in step B) according to the second operation mode, said gasification is run at partial capacity of the manufacturing system.

8. The process according to any of the preceding claims,wherein in step B), said gasification is carried out by using oxygen as an oxidant, wherein preferably at least a portion of said oxygen is obtained from water electrolysis, in particular driven by renewable energy, more preferably at least a portion of said oxygen is obtained from step C2).

9. The process according to any of the preceding claims,wherein in step B), said raw syngas has a stoichiometric number in the range from 0.3 to 2.5, preferably in the range from 0.8 to 2.0, more preferably in the range from 1.1 to 1.9, more preferably in the range from 1.2 to 1.8, e.g., about 0.8, 0.9, 1.0, 1.1, 1.2, 1.3, 1.4, 1.5, 1.6, 1.7, 1.8, 1.9, or 2.0.

10. The process according to any one of claims 6 to 9,wherein in step C1) according to the second operation mode, said WGS reaction is run at partial capacity of the manufacturing system.

11. The process according to any of the preceding claims,wherein in step D1), said first adjusted syngas stream has a stoichiometric number in the range from 1.9 to 3.0, preferably in the range from 2.0 to 2.5, more preferably in the range from 2.0 to 2.2, most preferably of approximately 2.1 or approximately 2.2; and / orwherein in step D2) and D3), respectively, said second adjusted syngas stream has a stoichiometric number in the range from 1.9 to 3.0, preferably in the range from 2.0 to 2.5, more preferably in the range from 2.0 to 2.2, most preferably of approximately 2.1 or approximately 2.2.

12. The process according to any of the preceding claims,wherein in step D3), at least a portion of said additional CO2 is obtained from step D1).

13. A process to produce at least one first downstream product being methanol -the process comprising the process according to any of the preceding claims and further comprising step E)BASF SE 240445W001- 36 - E) converting at least a portion of the first adjusted syngas stream from step D 1 ) and / or at least a portion of the second adjusted syngas stream from steps D2) or D3) to obtain methanol as first downstream product.

14. A system for producing syngas, the system comprising the unitsI) gasification unit;II) water-gas shift unit;III) CO2 capture unit;IV) CO2 storage unit;V) water electrolysis unit; andVI) mixing unit.

15. A process to operate a system for producing syngas according to claim 14, said process comprising the steps 51 ) operating the system in a first operation mode for a first period of time;52) switching the operation mode at the end of said first period of time from said first operation mode to a second operation mode, wherein said second operation mode is not identical to said first operation mode;53) operating the system in a second operation mode for a second period of time;54) switching the operation mode at the end of said second period of time from said second operation mode back to said first operation mode.

Images