Producing renewable hydrocarbons from biomass

Abstract

A process and a system for producing renewable hydrocarbons from biomass are provided.

Description

[0001] Producing Renewable Hydrocarbons from Biomass

[0002] Field of the Invention

[0003] This invention relates to a process for producing renewable hydrocarbons from biomass, the process comprising the steps of

[0004] A) providing biomass;

[0005] B) processing said biomass into a product stream and into at least one by-product stream;

[0006] C) subjecting said at least one by-product stream to anaerobic digestion to obtain biogas;

[0007] D) optionally upgrading said biogas to obtain upgraded biogas;

[0008] E) subjecting said biogas, optionally upgraded according to step D), to hydrogen production to obtain hydrogen; and

[0009] F) subjecting the product stream to catalytic hydrotreatment to obtain renewable hydrocarbons, wherein at least a part of the hydrogen produced in step E) is utilized for the hydrotreatment.

[0010] In addition, the invention relates to a system for carrying out said process for producing renewable hydrocarbons from biomass.

[0011] Background of the Invention

[0012] For 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 concentration in the atmosphere causing global warming and climate change. In view of the finite availability of fossil resources and the urgency to reduce carbon dioxide emissions, there is a high need to replace fossil carbon resources by renewable carbon resources.

[0013] Thus, the production of hydrocarbons from renewable resources like biomass, in particular for the use as fuels and base materials for chemical processes, has been attracting increasing interest. Such bio-based hydrocarbons exhibit a reduced product carbon footprint and reduce the demand for fossil carbon resources.

[0014] Animal fats, vegetable oils (e.g., rapeseed, soybean, palm, and camelina oil), waste oils and fats (e.g., used cooking oil, waste animal fats), microbial and algal oils, and fatty acids represent the most important biomass-derived raw materials for bio-based hydrocarbon production. Among the major pathways towards bio-based hydrocarbons is the catalytic hydrotreatment of these triglycerides and fatty acids, which includes hydrogenation, decarboxylation, decarbonylation, hydro-isomerization, and cracking processes under high temperature and pressure conditions, frequently also including a catalytic isomerization step, resulting in a hydrocarbon mixture comprising n- and iso-paraffins, among others. These reaction products may be further separated into gaseous and liquid fractions, which constitute valuable transportation fuels and chemical feedstocks, e.g., as renewable diesel (hydrotreated vegetable oils: HVOs; typically hydrocarbons with a final boiling point higher than 180 °C), renewable jet fuel (sustainable aviation fuel: SAF), bio-naphtha (a mixture of hydrocarbons mainly comprising paraffins, e.g. of up to 10 carbon atoms, that can be used - similar to naphtha of fossil origin - as a gasoline blending component or as a chemical feedstock, e.g., for crackers), and other low-boiling hydrocarbons (i.e. mainly C1-4 hydrocarbons, in particular C1-4 alkanes) like bio-based liquefied petroleum gas (LPG; e.g. biobased butane, propane, and ethane).

[0015] While said product streams are in principle fully bio-based regarding their carbon content, it must be borne in mind that hydrogen is needed for the hydrotreatment of the raw materials. To date, however, the predominant production routes of hydrogen are based on fossil fuels, mainly on steam reforming of natural gas (above all methane) and other light hydrocarbons. Thus, the production of hydrogen may represent a challenge where there is no well-developed natural gas infrastructure or where the use of natural gas should be avoided for sustainability reasons. In addition, using fossil feedstocks to produce hydrogen increases greenhouse gas emissions of the plant and thus increases the product carbon footprint (carbon intensity) of the products obtained on the basis of said hydrogen.

[0016] According to one approach to address these challenges of the bio-based hydrocarbon production process, low-boiling bio-based hydrocarbons (bio-Ci-4-HCs) and bio-naphtha obtained by the hydrotreatment process may be used as a source of hydrogen, e.g., as feedstocks for steam reforming or hydrocarbon pyrolysis. However, steam reforming and pyrolysis of bio-Cu-HCs and bio-naphtha is generally less efficient than methane reforming and pyrolysis, respectively. Because of the higher carbon content in such feeds, the product gas obtained in steam reforming contains more carbon oxides compared to a methane feed. Similarly, such feeds provide less hydrogen by pyrolysis than methane. Also, the use of the value products bio-Cu-HCs and bio-naphtha as hydrogen production feedstocks may be considered unfavorable from an economic perspective.

[0017] Thus, there is still a need to improve the carbon footprint of HVOs, SAF, bio-naphtha, and bio-Cu-HCs without compromising the yields and output of the value products.

[0018] Summary of the Invention

[0019] In a first aspect, the present invention relates to a process for producing renewable hydrocarbons from biomass, the process comprising the steps of

[0020] A) providing biomass;

[0021] B) processing said biomass into a product stream and into at least one by-product stream;

[0022] C) subjecting said at least one by-product stream to anaerobic digestion to obtain biogas;

[0023] D) optionally upgrading said biogas to obtain upgraded biogas;

[0024] E) subjecting said biogas, optionally upgraded according to step D), to hydrogen production to obtain hydrogen; and

[0025] F) subjecting the product stream to catalytic hydrotreatment to obtain renewable hydrocarbons, wherein at least a part of the hydrogen produced in step E) is utilized for the hydrotreatment.

[0026] In a second aspect, the invention relates to a system for producing renewable hydrocarbons from biomass according to the processes described herein, the system comprising

[0027] I) a biomass conversion unit for receiving biomass and processing said biomass into a product stream and into at least one by-product stream;

[0028] II) a biogas plant, connected and arranged downstream to unit I), for receiving at least one by-product stream from unit I), for producing biogas from said at least one by-product stream via anaerobic digestion, and optionally for upgrading said biogas to upgraded biogas;

[0029] III) a hydrogen production unit, connected and arranged downstream to unit II), for receiving said optionally upgraded biogas from unit II) and for producing hydrogen from said optionally upgraded biogas; and IV) a bio-oil refinery unit, connected and arranged downstream to units I) and III), for receiving said product stream from unit I) and said hydrogen from unit III) and for producing renewable hydrocarbons from said product stream and said hydrogen via catalytic hydrotreatment.

[0030] Further aspects of the present invention will become apparent to the person skilled in the art directly from the foregoing and following description and the examples.

[0031] Brief Description of the Drawings

[0032] FIG 1 : Flow diagram showing a process for co-producing HVO, SAF, bio-naphtha, and bio-Cu-HCs along with upgraded biogas from biomass and hydrogen

[0033] FIG 2: Flow diagram showing a process for co-producing HVO and SAF along with and upgraded biogas from biomass

[0034] FIG 3: Flow diagram showing a process for co-producing HVO, SAF, and bio-naphtha from biomass

[0035] FIG 4: Flow diagram showing a process for co-producing HVO, SAF, and bio-naphtha from biomass and further biogas feedstock

[0036] FIG 5: Flow diagram showing a process for co-producing HVO, SAF, bio-naphtha, and bio-Cu-HCs from biomass

[0037] FIG 6: Flow diagram showing a process for co-producing HVO, SAF, bio-naphtha, and bio-Cu-HCs from biomass and further biogas feedstock

[0038] FIG 7: System for performing the processes according to FIGs 1-6

[0039] Legend for FIG 1-7:

[0040] 1: biomass; 2: biomass residues and biomass waste; 3: biogas; 4: upgraded biogas; 5: hydrogen; 6: bio-oil; 7: HVO; 8: SAF; 9: bio-naphtha; 10: bio-Cu-HCs; 11 : conversion; 12: anaerobic digestion; 13: upgrading; 14: hydrogen production; 15: hydrotreatment; 16: separation; 17: further biogas feedstock

[0041] 101 : biomass conversion unit; 102: biogas plant; 103: hydrogen production unit; 104: bio-oil refinery unit

[0042] Detailed Description of the Invention

[0043] The present invention provides a process and a system for producing renewable hydrocarbons from biomass.

[0044] The production of renewable hydrocarbons from biomass typically starts with the conversion of biomass to bio-oil which is then further refined and / or upgraded, especially catalytically hydrotreated, to hydrocarbon fuels (HVO, SAF), bio-Ci-4- HCs, and bio-naphtha, which can be utilized as a gasoline blending component or as a feedstock for further petrochemical processes, in particular for steam cracking to produce olefins. The conversion of plant biomass into bio-oils typically comprises mechanical operations and chemical processes. As a side product of these treatments, biomass residues and biomass waste accrue that often are not or cannot be further employed for material use, but are used energetically only, if at all; in the alternative, they are deposited in landfills.

[0045] It is described herein that such residues and waste may be efficiently used as a feedstock in a biogas plant to produce biogas via anaerobic digestion. For that purpose, said residues and waste may also be complemented with and / or be replaced in full or in part by other biomass residues and biomass waste from other sources than bio-oil production. Said biogas, optionally after upgrading, may be utilized for (steam) reforming or hydrocarbon pyrolysis to provide hydrogen which in turn facilitates the hydrotreatment of bio-oils to HVO, SAF, bio-naphtha, and bio-Cu-HCs. Thus, by the process of the present invention, (upgraded) biogas produced from biomass residues and biomass waste may fully or at least in part replace other reforming or pyrolysis feedstocks, i.e., hydrogen sources, like natural gas and light hydrocarbons of fossil or renewable origin.

[0046] Therefore, the disclosed process is particularly advantageous where there is no well-established natural gas or light hydrocarbon infrastructure which could secure reliable supply of these raw materials for (steam) reforming or hydrocarbon pyrolysis. In addition, hydrocarbon pyrolysis as a hydrogen production technology delivers not only hydrogen, but also carbon as a value product while carbon dioxide process emissions are avoided; furthermore, it allows for efficient heat integration and changing feed compositions are rather unproblematic. Thus, importantly, the products obtained by hydrotreatment of bio-oils with said biomass-derived hydrogen may exhibit an improved carbon footprint. Also, they may be obtained in larger amounts since they do not need to be used partially as raw material for (steam) reforming, which is advantageous especially for renewable hydrocarbons with a limited availability on the market like bio-naphtha or bio-Ci-4- HCs. Hence, more of said renewable hydrocarbons may find economically more attractive applications. In turn, also biomass residues and biomass waste may therefore be considered for biogas production that have previously been regarded as hardly suitable for such purposes, e.g., as they have been regarded as poorly biodegradable or yielding low biogas amounts, or due to challenging volume or density characteristics or a vast spatial distribution. Thus, the disclosed process allows for a more complete conversion of biomass into value products. As a further benefit, the use of biomass residues and biomass waste for the biogas production avoids their deposition in landfills and the subsequent often uncontrolled emission of greenhouse gases from these landfills (above all methane and carbon dioxide) due to aerobic and anaerobic decomposition processes; instead, this opportunity to capture and use a relevant raw material resource is not lost but exploited advantageously in the context of the biorefinery processes.

[0047] Along these lines, a system for producing renewable hydrocarbons from biomass that allows to perform the herein-described process and to deliver the above-mentioned advantages may comprise a biomass conversion unit to convert biomass into bio-oil as a main product and into biomass residues and biomass waste as by-products, a biogas plant to produce (upgraded) biogas via anaerobic digestion of the biomass residues and biomass waste, a hydrogen production unit to produce hydrogen from hydrocarbons, and a bio-oil refinery unit to perform hydrotreatment of the bio-oil and further upgrading or refinery steps.

[0048] Said system furthermore allows for a flexibilization of the overall production pathways, both in terms of feedstock and in terms of product spectrum. In principle, the system is run with biomass and hydrogen to produce renewable fuels (HVO, SAF), bio-naphtha, bio-Ci-4-HCs, and (upgraded) biogas as main value products. In case external hydrogen supply is short or no external hydrogen supply is available at all, hydrogen may be produced internally in the hydrogen production unit from (upgraded) biogas obtained from the biogas plant. In this setup, the yields of renewable fuels, bio-naphtha, and bio-Ci-4-HCs are maximized. If on the other hand there are not enough biomass residues and biomass waste available, as may be the case for seasonal reasons, the hydrogen production unit may be fed with hydrocarbons, e.g., bio-Ci-4- HCs like propane and / or bio-naphtha, from the bio-oil refinery unit. Thus, the yields of renewable fuels are maximized. Further, if there is an abundancy of biomass, (upgraded) biogas may be obtained as an additional value product. Also, if there is a high demand for (upgraded) biogas, more of the bio-Cu-HCs or bio-naphtha may be used as a hydrogen production feedstock to maximize the (upgraded) biogas output.

[0049] Thus, in a first aspect, the present invention provides a process for producing renewable hydrocarbons from biomass, the process comprising the steps of

[0050] A) providing biomass;

[0051] B) processing said biomass into a product stream and into at least one by-product stream;

[0052] C) subjecting said at least one by-product stream to anaerobic digestion to obtain biogas;

[0053] D) optionally upgrading said biogas to obtain upgraded biogas;

[0054] E) subjecting said biogas, optionally upgraded according to step D), to hydrogen production to obtain hydrogen; and

[0055] F) subjecting the product stream to catalytic hydrotreatment to obtain renewable hydrocarbons, wherein at least a part of the hydrogen produced in step E) is utilized for the hydrotreatment.

[0056] 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 converted at least into bio-oils. In particular, the term biomass comprises plants or parts thereof like crops, wood, or residues thereof, marine organisms like algae, and bio waste such as organic food waste, e.g., animal fat from meat industry waste, fish fat from fish processing waste, or used cooking oil. Of note, the biomass provided may be composed of biomass streams from various of the above-mentioned sources.

[0057] According to one embodiment, the biomass provided in step A) is of vegetable or animal origin or a mixture thereof, preferably it is of vegetable origin.

[0058] According to another embodiment, the biomass provided in step A) is of vegetable origin, preferably it comprises or is derived from algae, oil crops, oil palms, soybeans, rapeseed, mustard, flax, cottonseed, sunflower, corn, castor beans, hemp, field pennycress, pongamia, jatropha, coconut palms, macauba palms, mahua, camelina, salicornia, carinata, lignocellulose, wood, forestry residues, agricultural residues, crop residues, straw, residues from vegetable oil production, residues from grain processing, green waste, food waste, and used vegetable cooking oil, more preferably it comprises or is derived from algae, oil crops, oil palms, soybeans, rapeseed, pongamia, sunflower, corn, castor beans, jatropha, coconut palms, macauba palms, camelina, and carinata, most preferably it comprises or is derived from oil palms, soybeans, rapeseed, jatropha, and macauba palms.

[0059] According to another embodiment, the biomass provided in step A) is of animal origin, preferably it comprises or is derived from animal fat, livestock-related products like tallow, fish fat, or food waste. The processing of biomass according to step B) may comprise both mechanical and physical operations, like harvesting and collecting as well as crushing, cracking, cutting, shredding, grinding, chipping, milling, extrusion, irradiation, squeezing, pressing, bleaching, desodoration, filtering, sieving, adsorption, and thermal treatments such as drying and torrefac- tion, and chemical processes, like extraction, distillation, thermochemical conversions like pyrolysis or hydrothermal liquefaction, gasification followed by Fischer-Tropsch processes, hydrolysis, saponification, neutralization, ketonization, or hydrogenation. Also, the mechanical, physical, and / or chemical separation of the products and by-products of said operations and processes, in particular the separation of gaseous, liquid, and solid fractions, forms part of the processing according to step B). In essence, step B) comprises the removal of all by-products from the product stream that are not suitable or are detrimental for further use as a feedstock for subsequent hydrotreatment. The right choice of suitable process steps and operating conditions is mainly dependent on the biomass to be processed; but the one skilled in the art will be familiar with such considerations, in particular when it comes to the production and processing of edible oils, vegetable oils, tall oils and the like.

[0060] The product stream obtained by said processing comprises, preferably consists of bio-oil. Bio-oil designates a liquid compound mixture mainly comprising highly oxygenated compounds (e.g., glycerides, esters, carboxylic acids, phenols, alcohols, ketones, aldehydes, furans, and sugars) and water, while its exact composition depends on the biomass feedstocks and the processing steps applied. The term bio-oil includes in particular vegetable oils like rapeseed oil, sunflower oil, soybean oil, corn oil, castor oil, jatropha oil, carinata oil, palm oil, and macauba palm (kernel or pulp) oil, and processing residues thereof (like palm fatty acid distillate or oil mill effluents), waste cooking oil, tall oil, animal fats, and oils obtained by thermochemical conversion of biomass, e.g. biomass-derived pyrolysis or hydrothermal liquefaction oils, as well as mixtures thereof. Vegetable oils are mainly composed of glycerides, in particular of triglycerides, I ,e. , esters formed from glycerol and fatty acids.

[0061] The at least one by-product stream obtained by said processing comprises biomass residues and / or biomass waste resulting from said processing. The amount and quality of these residues and waste containing streams depend on the biomass feedstocks and the processing steps applied. The by-product streams may comprise in particular solid, semisolid, and liquid components, such as organic residues like hulls, shells, gum, straw, cellulose, spent cake, oilseed cake, oilseed meal, oilseed residue, soapstock, distillates like palm fatty acid distillate, spent bleaching earth, woodchips, pulp, other plant residues, as well as effluents and effluent sludges containing organic material. Preferred oilseeds comprise soybean, rapeseed, sunflower, castor beans, jatropha, carinata, macauba palm, and oil palm. The above-mentioned byproduct components may be comprised in one single by-product stream or in more than one separated by-product streams.

[0062] It is to be understood that processing the biomass into a product stream and into at least one by-product stream may also comprise purification steps, e.g., to remove contaminants or impurities that may be detrimental for the further process steps or for further use of the end products of the process. Thus, for instance, the by-product stream may comprise biomass residues and biomass waste obtained in the course of processing, e.g., extraction, of biomass into vegetable oils as well as during the purification, refining, and use of said vegetable oils.

[0063] Thus, according to one embodiment, the processing of step B) comprises mechanical operations and / or chemical processes, optionally also the separation of the obtained products and by-products. According to another embodiment, the processing of step B) comprises extraction, pyrolysis, and / or hydrothermal liquefaction of the biomass provided in step A).

[0064] According to another embodiment, the processing of step B) yields a product stream comprising, preferably consisting of, bio-oil.

[0065] According to another embodiment, said bio-oil is a vegetable oil, preferably selected from the group consisting of rapeseed oil, sunflower oil, soybean oil, corn oil, castor oil, jatropha oil, carinata oil, palm oil, and macauba palm (kernel or pulp) oil.

[0066] According to another embodiment, said bio-oil is an oil obtained by thermochemical conversion of biomass.

[0067] According to another embodiment, the processing of step B) yields at least one by-product stream comprising biomass residues and / or biomass waste, preferably organic residues selected from hulls, shells, gum, straw, spent cake, oilseed residue, soapstock, woodchips, as well as effluents and effluent sludges containing organic material.

[0068] According to another embodiment, the processing of step B) yields at least one by-product stream comprising solid biomass residues and / or solid biomass waste.

[0069] According to another embodiment, the processing of step B) comprises purification steps applied to the product stream and / or to the at least one by-product stream.

[0070] Biogas is a mixture of methane (e.g., 45 % to 75 % (v / v)), carbon dioxide, and small quantities of other gases and contaminants like water vapor and nitrogen- or sulfur-containing gases (e.g., ammonia or hydrogen sulfide), its exact composition depending on the type of feedstock and the production route. The production of biogas from organic feedstock, e.g., from the at least one by-product stream in step C), via anaerobic digestion is known in the art and may be conducted as dry or wet digestion. To overcome digestion barriers, to enhance microbial digestion, and to improve dewatering and the quality of the digestate, the actual digestion step is typically preceded by a biomass pretreatment. Biomass pretreatment should be adapted to the biomass structure and characteristics and may include mechanical, physical, thermal, chemical, and biological steps as well as combinations thereof, e.g. biological-physicochemical, electrochemical or thermal-chemical (such as thermal-alkaline) pretreatments. More specifically, pretreatment may comprise process steps like crushing, shredding, slurrifying (i.e. adding liquid, in particular water), ultrasonication, microwave irradiation, electrokinetic and high-pressure homogenization.

[0071] Biogas production pathways include biodigesters (airtight systems in which microorganisms degrade organic material diluted in water), landfill gas recovery systems (capturing gas originating from anaerobic decomposition, e.g., of biomass and / or municipal solid waste in landfills, optionally including pipelines for the transport of the biogas from the landfill to the unit producing hydrogen from said biogas), and wastewater treatment plants (recovering organic matter from sewage sludge for use in anaerobic digestion). In addition to biogas, the anaerobic digestion of organic feedstock provides a digestate that may be dried (partly or completely) and further used as a fertilizer or soil conditioner or to feed animals, e.g., ruminants, A wide variety of feedstocks can be used for biogas production like agricultural and crop residues (e.g., from the harvest of wheat, maize, rice, other coarse grains, sugar beets, sugar cane, soybean, or other oilseeds), animal manure (e.g., from livestock including cattle, pigs, poultry, or sheep), organic fractions of industrial and municipal solid waste (e.g., food and green waste like leaves and grass, paper, cardboard, wood, or industrial waste from food-pro- cessing industry), and sewage or wastewater sludge.

[0072] Within the scope of this disclosure, it is also contemplated that the above-mentioned biogas feedstocks may be used for biogas production and that the one or more by-product streams obtained in step B) may be used for biogas production in admixture with one or more of the further biogas feedstocks mentioned above to increase yield and / or efficiency of the biogas production process. The ratio of the by-product streams to the further biogas feedstocks in said admixture may range from 100 % : 0 % (i.e., by-product streams only) to 0 % : 100 % (i.e., further biogas feedstocks only).

[0073] Thus, according to one embodiment, step C) comprises biomass pretreatment, preferably mechanical, physical, thermal, chemical, and biological steps as well as combinations thereof.

[0074] According to another embodiment, the anaerobic digestion of step C) is performed as dry and / or wet digestion, preferably as dry digestion.

[0075] According to another embodiment, the anaerobic digestion of step C) is performed in a biodigester, in a landfill, and / or in a wastewater treatment plant, preferably in a biodigester.

[0076] According to another embodiment, step C) comprises, preferably consists of, the substeps C1), C2a), and C3a):

[0077] C1) providing at least one feedstock for biogas production, preferably selected from agricultural and crop residues, animal manure, organic fractions of industrial and municipal solid waste, and sewage or wastewater sludge, more preferably selected from agricultural and crop residues, e.g., from rice, and animal manure;

[0078] C2a) mixing said at least one by-product stream with said at least one feedstock for biogas production; and C3a) subjecting the feedstock mixture of C2a) to anaerobic digestion to obtain biogas.

[0079] According to another embodiment, step C) comprises, preferably consists of, the substeps C1), C2b), and C3b):

[0080] C1) providing at least one feedstock for biogas production, preferably selected from agricultural and crop residues, animal manure, organic fractions of industrial and municipal solid waste, and sewage or wastewater sludge, more preferably selected from agricultural and crop residues, e.g., from rice, and animal manure;

[0081] C2b) optionally mixing at least two of said at least one feedstocks for biogas production; and

[0082] C3b) subjecting the at least one feedstock provided in C1) and / or the feedstock mixture of C2b) to anaerobic digestion to obtain biogas.

[0083] According to another embodiment, step C) comprises (partially or completely) drying the digestate obtained from anaerobic digestion of biogas production feedstock to obtain fertilizer, soil conditioner, and / or animal feed.

[0084] In optional step D), the biogas obtained in step C) is upgraded in that contaminants that might negatively impact subsequent process steps, in particular the hydrogen production step E), are removed completely or their amounts are reduced to levels that are tolerated by the subsequent process steps. Thus, upgraded biogas is obtained. Depending on the biogas and the subsequent process steps used, the skilled person will be well aware of relevant contaminants to be removed, of tolerable levels, and of technical measures to reduce their amounts. In particular, nitrogen- and sulfur-containing contaminants like ammonia or hydrogen sulfide may be subject to said purification. Processes for such biogas upgrading include water scrubbing, amine gas treatment, pressure swing adsorption, and membrane separation techniques, as well as other purification steps. In particular, biogas may be upgraded to biomethane, a preferred form of upgraded biogas. Upgrading of biogas to biomethane includes not only removing relevant contaminants, but also lowering the amounts of carbon dioxide in the biogas, which may be achieved by water scrubbing, amine gas treatment, pressure swing adsorption, and membrane separation techniques. Preferably, biomethane meets the specifications commonly used for natural gas grids, e.g., it typically contains not less than 75 % (v / v), preferably not less than 85 % (v / v), more preferably not less than 90 % (v / v) or 95% (v / v) methane. Correspondingly, biomethane typically contains not more than 25 % (v / v), preferably not more than 15 % (v / v), more preferably not more than 10 % (v / v), even more preferably not more than 5 % (v / v) or not more than 3 % (v / v) carbon dioxide.

[0085] As a further process step of biogas upgrading according to step D), compression of the (upgraded) biogas is contemplated within the scope of this invention. Compression may be necessary or desired to obtain (upgraded) biogas in a form suitable for further applications like storage, shipment, delivery, and / or use in subsequent process steps.

[0086] Thus, according to one embodiment, the optional biogas upgrading of step D) includes reducing the amounts of ammonia, hydrogen sulfide, water, and other impurities in the biogas, preferably reducing the amounts of ammonia and hydrogen sulfide in the biogas, preferably to levels tolerated by subsequent step E).

[0087] According to another embodiment, the optional biogas upgrading of step D) includes reducing the amount of carbon dioxide in the biogas, preferably to amounts of not more than 25 % (v / v), more preferably of not more than 15 % (v / v), even more preferably of not more than 10 % (v / v), most preferably of not more than 5 % (v / v) or of not more than 3 % (v / v) carbon dioxide.

[0088] According to another embodiment, the optional biogas upgrading of step D) includes water scrubbing, amine gas treatment, pressure swing adsorption, and / or membrane separation techniques.

[0089] According to another embodiment, the optional biogas upgrading of step D) includes compression of the (upgraded) biogas.

[0090] Hydrogen production may be carried out by reforming of hydrocarbons or pyrolysis of hydrocarbons.

[0091] Reforming of hydrocarbons is a mature process to produce hydrogen. The most important hydrocarbon reforming technologies are steam (methane) reforming, partial oxidation, and autothermal reforming (the latter being basically a combination of the former two processes), all of which are well-known to the one of skill in the art. For instance, in steam reforming, methane is reacted with steam in the presence of a catalyst under high temperature and high-pressure conditions, whereas in partial oxidation, methane is reacted with sub-stoichiometric amounts of oxygen. In both cases, a mixture consisting primarily of hydrogen, carbon monoxide, and relatively small amounts of carbon dioxide is obtained. A subsequent water-gas shift reaction allows for increasing the hydrogen yield further by converting carbon monoxide and water to hydrogen and carbon dioxide. The resulting gas stream may be finally purified by a pressure swing adsorption process to remove remaining impurities like carbon dioxide and to yield essentially pure hydrogen.

[0092] In hydrocarbon pyrolysis (also referred to as "hydrocarbon decomposition”), light hydrocarbons, in particular methane ("methane pyrolysis”), e.g., in the form of natural gas or biogas, is decomposed without the involvement of oxygen into hydrogen and solid, high-purity carbon (e.g., as carbon black, carbon powder, or granular carbon). In contrast to reforming, however, no gaseous carbon dioxide is produced, but solid carbon is formed as a by-product, which has a positive effect on economic efficiency and ecologic impact. Further, compared to water electrolysis, methane pyrolysis requires significantly less energy. Therefore, methane pyrolysis is considered a promising sustainable technology for future hydrogen production.

[0093] Hydrocarbon pyrolysis may be carried out in different ways known to the one skilled in the art (Muradov et al., International Journal Hydrogen Energy 2008, 33, 6804-6839; Abbas et al., International Journal Hydrogen Energy 2010, 35, 1160-1190); Dagle et al.: An Overview of Natural Gas Conversion Technolgies for Co-Production of Hydrogen and Value-Added Solid Carbon Products, Report by Argonne National Laboratory and Pacific Northwest National Laboratory (ANL-17 / 11, PNNL-26726, November 2017): catalytically or thermally, and with heat input via plasma, microwave, heated carrier gas, resistance heating, induction, liquid metal processes, or autothermally, in particular via plasma pyrolysis (WO 2015 / 116797, WO 2015 / 116800), metal melting / metal salt melting (WO 2020 / 161192, WO 2021 / 183959), moving bed process (US 2982622, WO 2019 / 145279, WO 2020 / 200522, WO 2023 / 057242), (fluidized bed) catalytic process (WO 2011 / 029144, WO 2016 / 154666), or partial / pulsed combustion (WO 2020 / 118417 and US 2022 / 0185664), the moving bed process being particularly advantageous due to its high efficiency, heat integration, flexibility, and favorable product carbon footprint. These processes differ I. a. in the form of the energy used (thermal, electrical, etc.), the process conditions (temperature, pressure, etc.), the catalysts, and / or auxiliary materials used. The pyrolysis process is preferably heated electrically, even more preferably by resistive heating (Joule heating) of the substrate material (US 2982622, WO 2019 / 145279, and WO 2020 / 200522).

[0094] The solid carbon type generated in the methane decomposition depends on the reaction conditions, reactor, and heating technology. Examples are carbon black from plasma processes carbon powder from liquid metal processes granular carbon from thermal decomposition in fixed, moving, or fluidized bed reactors.

[0095] The processing and separation of solid carbon depends on the chosen pyrolysis technology and is known by the person skilled in the art. For example, in a plasma pyrolysis process, the solid carbon in the form of carbon black is discharged from the reactor with the gas and then separated, e.g., by a cyclone. The solid carbon might be post-treated, e.g., agglomerated. Depending on the process and the metals used, in molten metal pyrolysis, the carbon floats on the melt and is skimmed off or leaves the reactor together with the gas stream and is then separated, e.g., by a filter or cyclone. In addition, a purification step to remove residual metal from the carbon could be required e.g., washing or evaporation. In the catalytic pyrolysis technology and in the fixed and moving bed technology, the solid carbon is deposited on the surface of the catalyst and / or support and taken off the reactor via the catalyst and / or support.

[0096] Thus, solid carbon may be separated by a cyclone or a filter and may be post-treated, e.g., to achieve agglomeration; further, the carbon may be purified by washing and / or evaporation techniques to remove, for instance, residual metal contamination. The resulting gas stream comprising hydrogen may be finally purified by a pressure swing adsorption process to remove remaining impurities like hydrogen sulfide, carbon oxides, hydrocarbons, and inert gases like nitrogen, to yield purified hydrogen.

[0097] Of note, other hydrocarbons than methane, e.g., the hydrocarbons obtained in step F) as described below, may be used as a co-feed for the hydrogen production step; this may be beneficial, for instance, in case the (upgraded) biogas production is insufficient to fully supply the hydrogen production process. In this case, the term "hydrocarbon reforming” and "hydrocarbon pyrolysis” as used herein, shall encompass not only methane reforming and methane pyrolysis, respectively, but also reforming and pyrolysis of such hydrocarbons.

[0098] In addition, while biogas upgraded according to step D) is preferably used as a feedstock, hydrogen production according to step E) may also be carried out with biogas without further upgrading, e.g., with biogas as provided by step C), as a feedstock. For being suitable for hydrogen production, said biogas may comprise up to 50 % (v / v) carbon dioxide, preferably up to 40 %, more preferably up to 30 %, even more preferably up to 25 %, most preferably up to 15 % (v / v) carbon dioxide.

[0099] Thus, the different above-mentioned hydrogen production feedstocks (biogas, upgraded biogas, and hydrocarbons like bio-naphtha and bio-Cu-HCs) may be used for hydrogen production according to step E) separately or in admixture, simultaneously or sequentially, with the mass fractions of (upgraded) biogas ranging from 0 % (i.e., bio-naphtha and / or bio-Ci-4-HCs only) to 100 % (i.e., biogas and upgraded biogas only), e.g., the mass fractions of (upgraded) biogas being approximately 20 %, 40 %, 60 %, 80 %, or 100 %, preferably not less than 50 % (m / m).

[0100] Accordingly, the hydrogen obtained in step E) may originate from biogas, upgraded biogas, and hydrocarbons like bionaphtha and bio-C 1-4-HCS, the mass fraction of hydrogen originating from biogas and upgraded biogas accounting for not less than approximately 10 %, 20 %, 30 %, 40 %, 50 %, 60 %, 70 %, 80 %, 90 % (m / m) of the total hydrogen obtained in step E), preferably not less than 25 %, more preferably not less than 50 % (m / m), even more preferably not less than 75 %, most preferably not less than 90 % (m / m). The given hydrogen mass fractions may be determined, calculated, or evaluated on the basis of a certain observation period, production cycle, or batch manufacturing in subsequent process steps.

[0101] Thus, according to one embodiment, hydrogen production in step E) is carried out by hydrocarbon reforming, in particular by steam reforming, partial oxidation, or autothermal reforming, preferably by steam reforming.

[0102] According to another embodiment, hydrogen production is carried out by hydrocarbon pyrolysis.

[0103] According to another embodiment, hydrogen production in step E) is carried out by hydrocarbon reforming and comprises the substeps E1), E2), and E3):

[0104] E1) steam reforming or partial oxidation or autothermal reforming of hydrocarbons, preferably methane, to obtain a first gas stream comprising hydrogen, carbon monoxide, and carbon dioxide;

[0105] E2) water-gas shift reaction of the first gas stream of E1) to obtain a second gas stream comprising, preferably consisting essentially of, hydrogen and carbon dioxide; and

[0106] E3) purification of the second gas stream of E2), preferably by pressure swing adsorption, to obtain a third gas stream consisting essentially of hydrogen.

[0107] According to another embodiment, hydrogen production in step E) is carried out by hydrocarbon pyrolysis and comprises the substeps E4), E5), and E6):

[0108] E4) hydrocarbon decomposition to obtain a first gas stream comprising hydrogen;

[0109] E5) processing of solid carbon, optionally carbon separation, carbon post-treatment, and / or carbon purification, to obtain a carbon stream comprising solid carbon; and

[0110] E6) purification of the first gas stream of E4), preferably by pressure swing adsorption, to obtain a second gas stream consisting essentially of hydrogen. According to another embodiment, hydrogen production is carried out with biogas as provided by step C), wherein the biogas comprises not more than 50 % (v / v) carbon dioxide, preferably not more than 25 % (v / v) carbon dioxide, more preferably not more than 15 % (v / v) carbon dioxide.

[0111] According to another embodiment, hydrogen production is carried out with upgraded biogas as provided by step D).

[0112] According to another embodiment, step E) additionally comprises subjecting hydrocarbons to hydrogen production to obtain hydrogen, wherein said hydrocarbons, preferably bio-Ci-4-HCs or bio-naphtha, originate preferably from step F) as described below.

[0113] According to another embodiment, the mass fraction of hydrogen originating from biogas and upgraded biogas accounts for not less than approximately 10 %, 20 %, 30 %, 40 %, 50 %, 60 %, 70 %, 80 %, 90 % (m / m) of the total hydrogen obtained in step E), preferably not less than 25 %, more preferably not less than 50 % (m / m), even more preferably not less than 75 %, most preferably not less than 90 % (m / m).

[0114] Catalytic hydrotreatment, i.e., chemical operations using hydrogen in the presence of a catalyst at high temperatures and pressures, is a well-established upgrading technology, e.g., for processing bio-oils, that includes more specifically the processes of hydrodeoxygenation (as well as the removal of other heteroatoms), hydrodemetallation, and hydrogenation of bio-oils. Furthermore, hydroisomerization and / or hydrocracking of the obtained renewable hydrocarbons may be encompassed in step F) to shift the relative yields of the different fractions in a desired way and / or to improve their properties and performances (e.g., at low temperatures) during further use, e.g., as fuels, fuel blendstocks, or as chemical feedstocks. Said hydroisomerization and hydrocracking may run simultaneously or sequentially to the other above- mentioned processes encompassed by catalytic hydrotreatment, e.g., to hydrogenation and / or hydrodeoxygenation. Large amounts of hydrogen are typically needed to accomplish the goal of converting bio-oils into renewable hydrocarbons that are suitable for further use, be it as fuels (in particular renewable diesel and renewable jet fuel) or as chemical feedstocks (in particular bio-naphtha). The exact composition of the obtained renewable hydrocarbon mixture will depend, for example, on the feedstock composition, the processing conditions, and the catalyst properties. Most of the available hydrogen being derived from fossil sources, the carbon footprint of such renewable hydrocarbons is often negatively impacted by the hydrogen demand. Therefore, according to the invention a part of the hydrogen needed for hydrotreatment of the product stream, especially of bio-oils, in step F) is provided from step E), i.e., from a renewable source. Hence, the carbon intensity of renewable hydrocarbons is further reduced by replacing hydrogen of fossil origin by hydrogen of renewable origin, as obtained in step E).

[0115] Thus, according to one embodiment, for the catalytic hydrotreatment in step F), at least a part of the hydrogen produced in step E), preferably essentially all of the hydrogen produced in step E), is utilized.

[0116] According to another embodiment, for the catalytic hydrotreatment in step F), at least a part of the hydrogen needed, preferably all of the hydrogen needed, is provided by the hydrogen produced in step E).

[0117] According to another embodiment, the renewable hydrocarbons obtained in step F) comprise one or more of renewable diesel, renewable jet fuel, bio-naphtha, and / or bio-Ci-4-HC (like propane) fractions, preferably they comprise a bio-naph- tha fraction. According to another embodiment, step F) comprises hydroisomerization to obtain renewable hydrocarbons.

[0118] According to another embodiment, step F) comprises hydrocracking to obtain renewable hydrocarbons.

[0119] Further

[0120] The 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 and separation steps may be applied to the product and / or by-product streams, e.g., in step B), and / or to any downstream process intermediates or products thereof, to improve their properties or to meet certain specifications.

[0121] Also, the products of step F) may be separated into different value products according to established fractionation techniques, especially to obtain separated renewable diesel, renewable jet fuel, bio-naphtha, and / or bio-Ci-4-HC (like propane) fractions.

[0122] Furthermore, an isomerization and / or cracking step of the obtained renewable hydrocarbons may be included in step F) to shift the relative yields of the different fractions in a desired way and / or to improve their properties and performances (e.g., at low temperatures) during further use, e.g., as fuels, fuel blendstocks, or as chemical feedstocks. Isomerization may, for example, be carried out as hydroisomerization and / or catalytic isomerization of the bio-naphtha fraction, with or without prior separation, to convert n-paraffins to iso-paraffins. Cracking may, for example, be carried out as hydrocracking and / or catalytic cracking of renewable diesel and / or renewable jet fuel fractions, with or without prior separation, e.g., to increase the yield of bio-naphtha and / or bio-Ci-4-HC (like propane) fractions and to decrease the yields of HVO and SAF fractions.

[0123] In addition, the products of said separation, e.g., the bio-naphtha fraction, and of said optional isomerization step may be further utilized in refinery or petrochemical processes, for instance as a blend stock for fuel blending or as a feedstock for steam cracking. Fuel blending is common to improve the characteristics of fuels, e.g., to optimize vapor pressure, octane number, boiling point, viscosity, sulfur content, color, stability, aromatics or olefin content. Steam cracking is the most important industrial process for producing lighter olefins, e.g., from naphtha.

[0124] Thus, according to one embodiment, the process according to the invention optionally comprises one or more of the following steps:

[0125] G) separating the renewable hydrocarbons into different fractions, preferably to obtain at least a separate naphtha fraction, at least a separate renewable diesel fraction, or at least a separate renewable jet fuel fraction;

[0126] H) subjecting the renewable hydrocarbons, preferably the naphtha fraction, to isomerization, preferably to form isoparaffins or subjecting the renewable hydrocarbons, preferably the renewable diesel fraction and / or the renewable jet fuel fraction to cracking, preferably to increase the yield of bio-naphtha; and / or

[0127] J) blending the naphtha fraction of the renewable hydrocarbons with at least one fuel, e.g., with gasoline, to obtain a fuel blend with improved characteristics, or subjecting the naphtha fraction of the renewable hydrocarbons to steam cracking to obtain olefins. The process according to the invention may also comprise a step of controlling hydrogen production, in terms of both sufficient amounts and desired attributes:

[0128] The controlling of the hydrogen production includes the determination of the hydrogen amount needed, i.e., the hydrogen demand, for the catalytic hydrotreatment of step F). This demand of course depends on the amount, type, composition, and properties (e.g., the oxygen content) of the product stream used as well as on the type and goals of the hydrotreatment reaction, i.e., to which degree hydrodeoxygenation, hydrogenation, hydrocracking, and hydroisomerization of the product stream are to be achieved. Determining the hydrogen demand includes establishing a reasonable amount of excess hydrogen for the catalytic hydrotreatment and taking into account hydrogen amounts that may be recovered after the hydrotreatment step. The term "determination” and the like as used herein refers to the process of reaching a conclusion or result and may encompass means and steps suitable for that purpose, in particular to gather information, including by way of measurements, analysis, research, or investigation, and to use technical considerations and logical reasoning, including process knowledge, mathematical calculations, and computer-aided approaches like simulations and predictions. The one of skill in the art will be aware of such methods and considerations to successfully perform the determination steps described herein. The determination of hydrogen demands and obtainable hydrogen amounts may refer to different time periods, e.g., to an hourly, daily, weekly, or monthly basis.

[0129] The controlling of the hydrogen production further includes the determination of the amount of hydrogen obtainable from step E), which depends on the amount, type, composition, and properties of the by-product stream used as well as on the process conditions applied in step E).

[0130] Thus, the controlling of the hydrogen production includes the determination of the amounts and compositions of the feedstocks available for the hydrogen production of step E), especially the amounts and compositions of the biogas feedstocks for step C), i.e., of the by-product stream as well as of the further biogas feedstocks, of the biogas obtained from steps C) and D), and of other hydrocarbons for hydrogen production, e.g., as obtained from step F). Again, these amounts and compositions will depend on the amounts, types, compositions, and properties of the used product and byproduct streams, respectively, as well as on the process conditions applied in steps C), D), and F). Also, these amounts and compositions will depend on the desired output of the different hydrocarbon fractions to be delivered from step F). On the basis of this information and the process knowledge of the hydrogen production techniques, the one of skill in the art will be able to predict and thus to determine with reasonable accuracy the amounts of hydrogen that are obtainable and are to be expected from the hydrogen production according to step E).

[0131] Controlling the hydrogen production is intended to meet the hydrogen demand of step F) and to ensure a continuous and sufficient hydrogen supply to step F). Thus, said controlling includes the controlling of the supply means to provide biogas feedstock to step C) and (upgraded) biogas and / or hydrocarbons to hydrogen production of step E). Controlling supply means may include controlling volumes, flow rates, and the like. Also said controlling includes controlling the hydrogen production of step E) and the hydrotreatment process of step F), e.g., by controlling their process parameters and conditions.

[0132] Controlling the hydrogen production may also be intended to adjust or modify attributes of the products of steps F) or J) and any downstream products obtained therefrom. In particular, these attributes may be sustainability attributes like product carbon footprint, carbon intensity, greenhouse gas emissions, sustainability certifications, renewable content, bio-based or biogenic content, recycling content, fossil-based content, energy sources used, energy efficiency, and the like. Controlling the hydrogen production allows for such attribute adjustment or modification due to the potentially different origins of the hydrogen employed, e.g., the feedstock from which it is obtained, the pathway according to which it is produced, or the energy which is used for its production. For instance, said controlling may accordingly be used to minimize the product-carbon footprint or the fossil-based content of products of steps F) or J) or downstream products obtained therefrom or to optimize their renewable content or energy efficiency. Thus, said controlling may include the assignment of qualitative and / or quantitative attributes, in particular sustainability attributes, to the hydrogen production input streams. On this basis, the volumes of the different hydrogen production input streams may be varied and adjusted to obtain a hydrogen stream with desired qualitative and / or quantitative attributes that is then provided to step F). Thus, products of steps F) or J) and downstream products with pre-defined desired attributes may be produced.

[0133] Of note, computer-aided methods and applications may be used to achieve the above-mentioned objectives by allowing for a straightforward, precise, and rapid controlling of the hydrogen production as described hereinbefore.

[0134] Thus, according to one embodiment, the process according to the invention further comprises step K)

[0135] K) controlling the hydrogen production.

[0136] According to another embodiment, step K) comprises the substeps

[0137] K1) determining the hydrogen demand of step F) (H-dem)',

[0138] K2) determining the amount of hydrogen obtainable from step E) carried out with biogas derived from said by-product stream via step C) and optional step D) (H-obt1) and determining the amount of hydrogen obtainable from step E) carried out with biogas obtained from said further biogas feedstocks via step C) and optional step D) (H-obt2) and determining the amount of hydrogen obtainable from step E) carried out with said hydrocarbons obtained from step F) (H-obt3)', and

[0139] K3) controlling supply means for providing said biogas from steps C) and optional step D) to step E) and controlling supply means for providing said hydrocarbons from step F) to step E), such that a total amount of hydrogen is provided by step E) that is sufficient to meet the hydrogen demand of step F) as determined in substep K1) and preferably such that the amount of said hydrocarbons from step F) used in step E) is minimized.

[0140] According to another embodiment, step K) comprises the substeps

[0141] K1 a) determining the hydrogen demand of step F) (H-dem) and defining at least one qualitative and / or quantitative attribute that said hydrogen should fulfill;

[0142] K2a) determining the amount of hydrogen obtainable from step E) carried out with biogas derived from said byproduct stream via step C) and optional step D) (H-obt1) and determining the amount of hydrogen obtainable from step E) carried out with biogas obtained from said further biogas feedstocks via step C) and optional step D) (H-obt2) and determining the amount of hydrogen obtainable from step E) carried out with said hydrocarbons obtained from step F) (H-obt3 ); and assigning at least one qualitative and / or quantitative attribute to said amounts of hydrogen from each of said sources; and

[0143] K3a) controlling supply means for providing said biogas from steps C) and optional step D) to step E) and controlling supply means for providing said hydrocarbons from step F) to step E), such that a total amount of hydrogen is provided by step E) that is sufficient to meet the hydrogen demand of step F) as determined in substep K1 a) and that fulfills the at least one qualitative and / or quantitative attribute as defined in substep K1a) and preferably such that the amount of said hydrocarbons from step F) used in step E) is minimized.

[0144] According to another embodiment, step K3) and step K3a), respectively, comprise the substeps of determining the difference H-diff = (H-obt1 + H-obt2) - (H-dem) and if H-diff > 0, controlling the supply means for providing said hydrocarbons from step F) to step E) such that no hydrocarbons from step F) are passed to step E), and if H-diff < 0, controlling the supply means such that hydrocarbons from step F) are passed to step E) such that H-obt3 > -(H-diff).

[0145] Of note, whenever used hereinbefore or hereinafter, 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.

[0146] 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 1-6.

[0147] FIG 1 depicts a process for the co-production of HVO (7), SAF (8), bio-naphtha (9), and bio-Cu-HCs along with (upgraded) biogas (3, 4) from biomass (1) and hydrogen (5). The initial step is the conversion (11) of biomass (1) into a biooil (6) and biomass residues and biomass waste (2). Said biomass residues and biomass waste (2) undergo anaerobic digestion (12) to form biogas (3) which is optionally further upgraded to upgraded biogas (4). The bio-oil (6) is subjected to hydrotreatment (15) in the presence of hydrogen (5) and the obtained products are separated (16) to yield fractions like HVO (7), SAF (8), bio-naphtha (9), and bio-Cu-HCs (10).

[0148] FIG 2 depicts a process for the co-production of HVO (7), SAF (8) along with (upgraded) biogas (3, 4) from biomass (1). The process of FIG 2 differs from the one depicted in FIG 1 by the fact that bio-naphtha (9) and / or bio-Cu-HCs (10) are used as feedstocks for hydrogen production (14) to produce hydrogen (5) needed for hydrotreatment (15). Of note, FIG 2 is intended to include the case that not all of the bio-naphtha (9) and / or not all of the bio-Cu-HCs (10), but only parts thereof are used for hydrogen production (14). Likewise, FIG 2 is intended to include the case that not all the hydrogen (5) needed for hydrotreatment (15) originates from bio-naphtha (9) and / or bio-Cu-HCs (10), but a part thereof may originate from other sources.

[0149] FIG 3 depicts a process for the co-production of HVO (7), SAF (8), and bio-naphtha (9) from biomass (1). The process of FIG 3 differs from the one depicted in FIG 1 by the fact that bio-Cu-HCs (10) and upgraded biogas (4) are used as feedstocks for hydrogen production (14) to produce hydrogen (5) needed for hydrotreatment (15). Of note, FIG 3 is intended to include the cases that not all of the bio-Cu-HCs (10) and / or not all the upgraded biogas (4), but only parts thereof are used for hydrogen production (14). Likewise, FIG 3 is intended to include the case that not all the hydrogen (5) needed for hydrotreatment (15) originates from bio-Cu-HCs (10) and / or upgraded biogas (4), but a part thereof may originate from other sources. It is also contemplated that the biogas upgrading step (13) is optional such that biogas (3) may be used as a hydrogen production (14) feedstock in addition to or instead of upgraded biogas (4).

[0150] FIG 4 depicts a process for the co-production of HVO (7), SAF (8), and bio-naphtha (9) from biomass (1) and further biogas feedstock (17). The process of FIG 4 differs from the one depicted in FIG 3 by the fact that, along with biomass residues and biomass waste (2), further biogas feedstock (17) is used for anaerobic digestion (12) to produce biogas (3). FIG 5 depicts a process for the co-production of HVO (7), SAF (8), bio-naphtha (9), and bio-Cu-HCs (10) from biomass (1). The process of FIG 5 differs from the one depicted in FIG 1 by the fact that upgraded biogas (4) is used as a feedstock for hydrogen production (14) to produce hydrogen (5) needed for hydrotreatment (15). Of note, FIG 5 is intended to include the case that not all the upgraded biogas (4), but only parts thereof are used for hydrogen production (14). Likewise, FIG 5 is intended to include the case that not all the hydrogen (5) needed for hydrotreatment (15) originates from upgraded biogas (4), but a part thereof may originate from other sources. It is also contemplated that the biogas upgrading step (13) is optional such that biogas (3) may be used as a hydrogen production (14) feedstock in addition to or instead of upgraded biogas (4).

[0151] FIG 6 depicts a process for the co-production of HVO (7), SAF (8), bio-naphtha (9), and bio-Cu-HCs (10) from biomass (1). The process of FIG 6 differs from the one depicted in FIG 5 by the fact that, along with biomass residues and biomass waste (2), further biogas feedstock (17) is used for anaerobic digestion (12) to produce biogas (3).

[0152] Thus, in a second aspect, the present invention provides a system for producing renewable hydrocarbons from biomass according to the processes described herein, the system comprising

[0153] I) a biomass conversion unit for receiving biomass and processing said biomass into a product stream and into at least one by-product stream;

[0154] II) a biogas plant, connected and arranged downstream to unit I), for receiving at least one by-product stream from unit I), for producing biogas from said at least one by-product stream via anaerobic digestion, and optionally for upgrading said biogas to upgraded biogas;

[0155] III) a hydrogen production unit, connected and arranged downstream to unit II), for receiving said optionally upgraded biogas from unit II) and for producing hydrogen from said optionally upgraded biogas; and

[0156] IV) a bio-oil refinery unit, connected and arranged downstream to units I) and III), for receiving said product stream from unit I) and said hydrogen from unit III) and for producing renewable hydrocarbons from said product stream and said hydrogen via catalytic hydrotreatment.

[0157] Unit I)

[0158] The biomass conversion unit is fed with biomass as described hereinbefore. It is equipped to process said biomass as described for step B) above, including its different embodiments.

[0159] Thus, according to one embodiment, the biomass conversion unit is equipped to carry out mechanical operations and / or chemical processes, optionally also the separation of the obtained products and by-products.

[0160] According to another embodiment, the biomass conversion unit is equipped to perform extraction, pyrolysis, and / or hydrothermal liquefaction of said biomass. According to another embodiment, the biomass conversion unit is equipped to yield a product stream comprising, preferably consisting of, bio-oil.

[0161] According to another embodiment, the biomass conversion unit is equipped to yield at least one by-product stream comprising biomass residues and / or biomass waste, preferably organic residues selected from hulls, shells, gum, straw, spent cake, soapstock, woodchips, as well as effluents and effluent sludges containing organic material.

[0162] According to another embodiment, the biomass conversion unit is equipped to apply purification steps to the product stream and / or to the at least one by-product stream.

[0163] Unit II)

[0164] The biogas plant may be fed with at least one by-product stream from unit I); also, it may be fed with other feedstocks for biogas production, as described hereinbefore, as well as with admixtures of said by-product streams and other feedstocks. The biogas plant is equipped to produce biogas from said at least one by-product stream as described for step C) above, including its different embodiments, and is optionally equipped to upgrade said biogas to upgraded biogas, as described for step D) above, including its different embodiments.

[0165] Thus, according to one embodiment, the biogas plant comprises a biomass pretreatment unit.

[0166] According to another embodiment, the biogas plant is equipped to perform anaerobic digestion of said at least one byproduct stream as dry and / or wet digestion, preferably as dry digestion.

[0167] According to another embodiment, the biogas plant comprises a biodigester, a landfill, and / or a wastewater treatment plant, preferably a biodigester, to perform the anaerobic digestion of said at least one by-product stream.

[0168] According to another embodiment, the biogas plant comprises the subunits IIA) and II B):

[0169] 11 A) mixing unit, connected and arranged downstream to unit I), for receiving at least one by-product stream from unit I) and for mixing it with at least one feedstock for biogas production, preferably selected from agricultural and crop residues, animal manure, organic fractions of industrial and municipal solid waste, and wastewater sludge, more preferably selected from agricultural and crop residues and animal manure; and

[0170] I IB) anaerobic digestion unit, connected and arranged downstream to unit IIA), for receiving the feedstock mixture from unit IIA) and for subjecting said feedstock mixture to anaerobic digestion to obtain biogas.

[0171] According to another embodiment, the biogas plant is equipped to upgrade said biogas via water scrubbing and / or membrane separation techniques, especially to remove carbon dioxide from the biogas.

[0172] According to another embodiment, the biogas plant comprises a compression unit for compressing biogas and / or upgraded biogas.

[0173] Unit ill)

[0174] The hydrogen production unit comprises, preferably consists of, a reforming unit and / or a pyrolysis unit. It may be fed with (optionally upgraded) biogas from unit II). It is equipped to perform hydrogen production, e.g., hydrocarbon reforming and / or hydrocarbon pyrolysis, as described for step E) above, including its different embodiments.

[0175] Also, the hydrogen production unit may be connected to unit IV), as described hereinbefore and hereinafter, such that it may be fed with hydrocarbons from unit IV) for reforming and / or pyrolysis. In this case, the terms "hydrocarbon reforming” and "hydrocarbon pyrolysis” as used herein, shall encompass not only methane reforming and methane pyrolysis, respectively, but also reforming and pyrolysis of hydrocarbons, e.g., from unit IV). Thus, in this case, unit III) is connected downstream to unit IV) in respect of the product stream (i.e. in respect of the hydrocarbon stream), while it is connected upstream to unit IV) in respect of the by-product stream (i.e. in respect of the hydrogen stream); i.e., unit III) may provide hydrogen to unit IV) and may receive hydrocarbons from unit IV).

[0176] In this situation, where both (upgraded) biogas from unit II) and hydrocarbons from unit IV) may serve as feedstocks for the hydrogen production unit, unit III) may also comprise means like a control unit to adjust the flow rates of the (upgraded) biogas and hydrocarbon streams such that a continuous and sufficient feedstock supply of unit III) is ensured. Thus, according to one embodiment, the hydrogen production unit comprises, preferably consists of, a reforming unit and / or a pyrolysis unit.

[0177] According to another embodiment, the hydrogen production unit comprises, preferably consists of, a reforming unit that is equipped to perform hydrocarbon reforming by steam reforming, partial oxidation, or autothermal reforming.

[0178] According to another embodiment, the hydrogen production unit comprises, preferably consists of, a pyrolysis unit that is equipped to perform hydrocarbon pyrolysis.

[0179] According to another embodiment, the hydrogen production unit comprises, preferably consists of, a reforming unit that comprises the subunits IIIA), IIIB), and IIIC):

[0180] IIIA) steam reforming unit or partial oxidation unit or autothermal reforming unit, connected and arranged downstream to unit II), for reforming hydrocarbons, preferably methane, to obtain a first gas stream comprising hydrogen, carbon monoxide, and carbon dioxide;

[0181] IIIB) water-gas shift unit, connected and arranged downstream to unit IIIA), for performing the water-gas shift reaction for the first gas stream from unit IIIA) to obtain a second gas stream comprising, preferably consisting essentially of, hydrogen and carbon dioxide; and

[0182] IIIC) purification unit, connected and arranged downstream to unit IIIB), for purifying the second gas stream from unit IIIB), preferably by pressure swing adsorption, to obtain a third gas stream consisting essentially of hydrogen.

[0183] According to another embodiment, the hydrogen production unit comprises, preferably consists of, a pyrolysis unit that comprises the subunits HID), HIE), and II IF):

[0184] HID) hydrocarbon decomposition unit, connected and arranged downstream to unit II), for decomposing methane to obtain a first gas stream comprising hydrogen;

[0185] HIE) solid processing unit, connected and arranged downstream to unit HID), for processing solid carbon, optionally comprising a carbon separation unit, a carbon post-treatment unit, and / or a carbon purification unit, to obtain a carbon stream comprising, preferably consisting essentially of, solid carbon; and

[0186] II IF) purification unit, connected and arranged downstream to unit HID), for purifying the first gas stream from unit HID), preferably by pressure swing adsorption, to obtain a second gas stream consisting essentially of hydrogen. According to another embodiment, the unit III) is connected downstream to unit IV) in respect of the product stream and it is connected upstream to unit IV) in respect of the by-product stream.

[0187] According to another embodiment, when connected downstream to unit IV) in respect of the product stream, unit III) additionally comprises a control unit to adjust the flow rates of (upgraded) biogas from unit II) and hydrocarbons from unit IV), in particular to ensure continuous and sufficient feedstock supply. Unit IV)

[0188] The bio-oil refinery unit is fed with the product stream from unit I) and hydrogen from unit III). It is equipped to perform hydrotreatment of the product stream, in particular of bio-oil, and further upgrading or refinery steps, as described for step F) above, including its different embodiments.

[0189] Thus, according to one embodiment, the bio-oil refinery unit is equipped to perform catalytic hydrotreatment, wherein at least a part of the hydrogen produced from unit III), preferably essentially all of the hydrogen from unit III), is utilized. According to another embodiment, the bio-oil refinery unit is equipped to perform catalytic hydrotreatment, wherein at least a part of the hydrogen needed, preferably all of the hydrogen needed, is provided by the hydrogen from unit III). According to another embodiment, the bio-oil refinery unit is equipped to produce renewable hydrocarbons comprising renewable diesel, renewable jet fuel, bio-naphtha, and / or bio-Ci-4-HC (like propane) fractions, preferably comprising a bio-naphtha fraction.

[0190] According to another embodiment, the bio-oil refinery unit is equipped to further perform isomerization of the renewable hydrocarbons, preferably to form iso-paraffins.

[0191] Further units

[0192] The system according to the invention may comprise further units and sub-units, e.g., for performing the further process steps described above, like purification and separation of product and / or by-product streams and / or to any downstream process intermediates or products thereof, for instance, it may also comprise one or more fractionation and isomerization units.

[0193] Thus, according to one embodiment, the system according to the invention optionally comprises unit V):

[0194] V) fractionation unit, connected and arranged downstream to unit IV) for separating the renewable hydrocarbons into different fractions, preferably to obtain at least a separate naphtha fraction.

[0195] The system according to the invention may also comprise a hydrogen production control unit VI) that is equipped to interact with other units of the system and to carry out the controlling of the hydrogen production as described above for step K) and its different embodiments. In particular, the hydrogen production control unit VI) may adjust flow volumes and flow rates between the units of the system such that a continuous and sufficient hydrogen supply for the bio-oil refinery unit IV) is ensured and / or the hydrogen provided to unit IV) furthermore fulfills certain desired attributes. To this end, it may comprise computer systems to aid in a straightforward, precise, and rapid controlling of the hydrogen production as described for step K).

[0196] Thus, according to one embodiment, the system according to the invention further comprises the unit VI) VI) a hydrogen production control unit for controlling the hydrogen production.

[0197] According to another embodiment, unit VI) is equipped to interact with units II), III), IV), and V).

[0198] According to another embodiment, unit VI) is equipped to determine the hydrogen demand of unit IV) (H-dem), to determine the amounts of hydrogen obtainable from unit III) on the basis of biogas from unit II) obtained from said by-product stream (H-obt1) and / or from said further biogas feedstocks (H-obt2) and on the basis of said hydrocarbons from unit IV) (H-obt3), and to control supply means for providing said biogas from unit II) and said hydrocarbons from unit IV) to unit III), so that a total amount of hydrogen is provided that is sufficient to meet the hydrogen demand of unit IV) and preferably such that the amount of said hydrocarbons from unit IV) used in unit III) is minimized.

[0199] The term "being 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.

[0200] 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 7.

[0201] FIG 7 depicts a system for performing the processes according to FIG 1-6. A biomass conversion unit (101) receives biomass (1) to produce bio-oil (6) and biomass residues and biomass waste (2). The latter (2) is fed into a biogas plant (102), which may receive further biogas feedstock (17), to produce (optionally upgraded) biogas (3, 4). The hydrogen production unit (103) may receive said (optionally upgraded) biogas (3, 4) or a part thereof to produce hydrogen (5); also, the hydrogen production unit (103) may receive bio-naphtha (9) or a part thereof and / or bio-Ci -HCs (10) or a part thereof as feedstocks. The bio-oil refinery unit (104) receives bio-oil (6) as well as hydrogen (5), either from an external source or from the hydrogen production unit (103), to produce and separate HVO (7), SAF (8), bio-naphtha (9), and / or bio-Ci.4-HCs (10).

[0202] Examples

[0203] The 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.

[0204] 1) Process for Producing Bio-naphtha from Oil Palms

[0205] Oil palm fruit bunches are harvested and delivered to an oil mill, where palm oil is extracted and processed. These harvesting and production processes generate large amounts of biomass residues and biomass waste like empty fruit bunches, palm kernel shells, trunk of the plant, fibre, and leaves as well as effluents with high organic matter, suspended matter and oil and grease. Said residues and waste are pre-treated mechanically, e.g., they are cut and shredded to make them suitable for further processing, optionally mixed with further biogas feedstock such as rice crop residues, and subjected to biogas production via anaerobic digestion, optionally followed by upgrading to upgraded biogas. From said (optionally upgraded) biogas, hydrogen is produced via steam reforming or pyrolysis. The hydrogen is used for the hydrotreatment of the palm oil. The reaction products of this process are separated into HVO, SAF, and bio-naphtha fractions. The bio-naphtha fraction may be used as a blendstock for fuel blending or as a feedstock for further petrochemical processes like steam cracking to produce olefins; in the alternative, it may be used along with said (optionally upgraded) biogas as a feedstock to produce hydrogen via steam reforming or pyrolysis. 2) Process for Producing Bio-naphtha from Soybeans

[0206] Soybeans are harvested, cracked, and solvent-extracted with hexanes to obtain soybean oil and biomass residues and biomass waste, comprising soybean hulls, soybean residue, spent cake, soapstock, and gum. Said residues and waste are pre-treated mechanically, e.g., cut and shredded to make them suitable for further processing, optionally mixed with further biogas feedstock such as manure and rice crop residues, and subjected to biogas production via anaerobic digestion, optionally followed by upgrading to upgraded biogas. From said (optionally upgraded) biogas, hydrogen is produced via steam reforming or pyrolysis. The hydrogen is used for the hydrotreatment of the soybean oil. The reaction products of this process are separated into HVO, SAF, and bio-naphtha fractions. The bio-naphtha fraction may be used as a blendstock for fuel blending or as a feedstock for further petrochemical processes like steam cracking to produce olefins; in the alternative, it may be used along with said (optionally upgraded) biogas as a feedstock to produce hydrogen via steam reforming or pyrolysis.

[0207] The following set of embodiments further illustrates, but in no way restricts the present invention as described herein. Being directed to preferred embodiments, it represents a suitably structured part of the description and thus supports, but does not represent the claims of the present invention.

[0208] Preferred Embodiments

[0209] 1. A process for producing renewable hydrocarbons from biomass, the process comprising the steps of

[0210] A) providing biomass;

[0211] B) processing said biomass into a product stream and into at least one by-product stream;

[0212] C) subjecting said at least one by-product stream to anaerobic digestion to obtain biogas;

[0213] D) optionally upgrading said biogas to obtain upgraded biogas;

[0214] E) subjecting said biogas, optionally upgraded according to step D), to hydrogen production to obtain hydrogen; and

[0215] F) subjecting the product stream to catalytic hydrotreatment to obtain renewable hydrocarbons, wherein at least a part of the hydrogen produced in step E) is utilized for the hydrotreatment.

[0216] 2. The process of embodiment 1, wherein in step A) the biomass is of vegetable origin, preferably comprising or being derived from oil palms, soybeans, rapeseed, jatropha, and macauba palms, and / or of animal origin, preferably comprising or being derived from animal fat, livestock-related products like tallow, fish fat, or food waste.

[0217] 3. The process of one or more of embodiments 1-2, wherein in step B) the product stream comprises bio-oil and the at least one by-product stream comprises biomass residues and / or biomass waste.

[0218] 4. The process of one or more of embodiments 1-3, wherein step C) is replaced by step Ca) comprising the substeps C1), C2a), and C3a):

[0219] C1) providing at least one feedstock for biogas production, preferably selected from agricultural and crop residues, animal manure, organic fractions of industrial and municipal solid waste, and sewage or wastewater sludge, more preferably selected from agricultural and crop residues, e.g., from rice, and animal manure;

[0220] C2a) mixing said at least one by-product stream with said at least one feedstock for biogas production; and C3a) subjecting the feedstock mixture of C2a) to anaerobic digestion to obtain biogas; or wherein step C) is replaced by step Cb) comprising the substeps C1), C2b), and C3b):

[0221] C1) providing at least one feedstock for biogas production, preferably selected from agricultural and crop residues, animal manure, organic fractions of industrial and municipal solid waste, and sewage or wastewater sludge, more preferably selected from agricultural and crop residues, e.g., from rice, and animal manure;

[0222] C2b) optionally mixing at least two of said at least one feedstocks for biogas production; and

[0223] C3b) subjecting the at least one feedstock provided in C1) and / or the feedstock mixture of C2b) to anaerobic digestion to obtain biogas.

[0224] 5. The process of one or more of embodiments 1-4, wherein in step C) the anaerobic digestion is performed in a biodigester.

[0225] 6. The process of one or more of embodiments 1-5, wherein in step D) the upgrading includes water scrubbing, amine gas treatment, pressure swing adsorption, and / or membrane separation techniques.

[0226] 7. The process of one or more of embodiments 1-5, wherein in step E) hydrogen production is carried out by hydrocarbon reforming and comprises the substeps E1), E2), and E3)

[0227] E1) steam reforming to obtain a first gas stream comprising hydrogen, carbon monoxide, and carbon dioxide;

[0228] E2) water-gas shift reaction of the first gas stream of E1) to obtain a second gas stream comprising hydrogen and carbon dioxide; and

[0229] E3) purification of the second gas stream of E2), preferably by pressure swing adsorption, to obtain a third gas stream consisting essentially of hydrogen; or hydrogen production is carried out by hydrocarbon pyrolysis and comprises the substeps E4), E5), and E6):

[0230] E4) hydrocarbon decomposition to obtain a first gas stream comprising hydrogen;

[0231] E5) processing of solid carbon, optionally carbon separation, post-treatment, and / or carbon purification, to obtain a carbon stream comprising solid carbon; and

[0232] E6) purification of the first gas stream of E4), preferably by pressure swing adsorption, to obtain a second gas stream consisting essentially of hydrogen.

[0233] 8. The process of one or more of embodiments 1-7, wherein in step F) for the catalytic hydrotreatment, at least a part of the hydrogen needed is provided by the hydrogen produced in step E) and / or the renewable hydrocarbons obtained in step F) comprise one or more of renewable diesel, renewable jet fuel, bio-naph- tha, and / or bio-Ci -4-HC fractions, preferably they comprise a bio-naphtha fraction.

[0234] 9. The process of one or more of embodiments 1-8, additionally comprising step G)

[0235] G) separating the renewable hydrocarbons into different fractions, preferably to obtain at least a separate naphtha fraction.

[0236] 10. The process of one or more of embodiments 1-9, additionally comprising step H)

[0237] H) subjecting the renewable hydrocarbons, preferably the naphtha fraction, to isomerization, preferably to form iso-paraffins. 11. The process of one or more of embodiments 1-10, additionally comprising step J)

[0238] J) blending the naphtha fraction of the renewable hydrocarbons with at least one fuel, e.g., with gasoline, to obtain a fuel blend with improved characteristics, or subjecting the naphtha fraction of the renewable hydrocarbons to steam cracking to obtain olefins.

[0239] 12. A system for producing renewable hydrocarbons from biomass according to the processes described herein, the system comprising

[0240] I) a biomass conversion unit for receiving biomass and processing said biomass into a product stream and into at least one by-product stream;

[0241] II) a biogas plant, connected and arranged downstream to unit I), for receiving at least one by-product stream from unit I), for producing biogas from said at least one by-product stream via anaerobic digestion, and optionally for upgrading said biogas to upgraded bio-gas;

[0242] III) a hydrogen production unit, connected and arranged downstream to unit II), for receiving said optionally upgraded biogas, from unit II) and for producing hydrogen from said optionally upgraded biogas; and

[0243] IV) a bio-oil refinery unit, connected and arranged downstream to units I) and III), for receiving said product stream from unit I) and said hydrogen from unit III) and for producing renewable hydrocarbons from said product stream and said hydrogen via catalytic hydrotreatment.

[0244] 13. The system according to embodiment 12, wherein the biogas plant comprises the subunits 11 A) and I IB)

[0245] 11 A) mixing unit, connected and arranged downstream to unit I), for receiving at least one by-product stream from unit I) and for mixing it with at least one feedstock for biogas production, preferably selected from agricultural and crop residues and animal manure; and

[0246] I IB) anaerobic digestion unit, connected and arranged downstream to unit 11 A), for receiving the feedstock mixture from unit IIA) and for subjecting said feedstock mixture to anaerobic digestion to obtain biogas.

[0247] 14. The system according to one or more of embodiments 12-13, wherein the hydrogen production unit comprises, preferably consists of, a reforming unit that comprises the subunits I II A), I IIB), and IIIC):

[0248] IIIA) steam reforming unit or partial oxidation unit or autothermal reforming unit, connected and arranged downstream to unit II), for reforming hydrocarbons, preferably methane, to obtain a first gas stream comprising hydrogen, carbon monoxide, and carbon dioxide;

[0249] II IB) water-gas shift unit, connected and arranged downstream to unit IIIA), for performing the water-gas shift reaction for the first gas stream from unit IIIA) to obtain a second gas stream comprising hydrogen and carbon dioxide; and

[0250] IIIC) purification unit, connected and arranged downstream to unit II IB), for purifying the second gas stream from unit II IB), preferably by pressure swing adsorption, to obtain a third gas stream consisting essentially of hydrogen; or wherein the hydrogen production unit comprises, preferably consists of, a pyrolysis unit that comprises the subunits HID), HIE), and lllF):

[0251] HID) hydrocarbon decomposition unit, connected and arranged downstream to unit II), for decomposing methane to obtain a first gas stream comprising hydrogen; HIE) solid processing unit, connected and arranged downstream to unit HID), for processing solid carbon, optionally comprising a carbon separation unit, carbon post-treatment unit, and / or a carbon purification unit, to obtain a carbon stream comprising, preferably consisting essentially of, solid carbon; and

[0252] II IF) purification unit, connected and arranged downstream to unit HID), for purifying the first gas stream from unit HID), preferably by pressure swing adsorption, to obtain a second gas stream consisting essentially of hydrogen.

[0253] 15. The system according to one or more of embodiments 12-14, additionally comprising unit V):

[0254] V) fractionation unit, connected and arranged downstream to unit IV) for separating the renewable hydrocarbons into different fractions, preferably to obtain at least a separate naphtha fraction.

[0255] 16. The process according to one or more of embodiments 1-11 , wherein in step B) said processing comprises mechanical operations and / or chemical processes, wherein preferably at least one of said operations and / or processes is selected from the group consisting of grinding, milling, extrusion, squeezing, pressing, and extraction, and or wherein said processing comprises hydrothermal liquefaction of the biomass provided in step A).

[0256] 17. The process according to one or more of embodiments 1-11 and 16, wherein in step B) said product stream comprises bio-oil and said at least one by-product stream comprises biomass residues and / or biomass waste.

[0257] 18. The process according to one or more of embodiments 1-11 and 16-17, wherein in step B) said product stream comprises vegetable oil and / or said at least one by-product stream comprises solid biomass residues and / or solid biomass waste.

[0258] 19. The process according to one or more of embodiments 1-11 and 16-18, wherein in step F) said renewable hydrocarbons comprise a bio-naphtha fraction.

Claims

Claims1. A process for producing renewable hydrocarbons from biomass, the process comprising the steps ofA) providing biomass;B) processing said biomass into a product stream and into at least one by-product stream, wherein said processing comprises mechanical operations and / or chemical processes, wherein preferably at least one of said operations and / or processes is selected from the group consisting of grinding, milling, extrusion, squeezing, pressing, and extraction, and wherein said product stream comprises vegetable oil, and wherein said at least one by-product stream comprises biomass residues and / or biomass waste; or wherein said processing comprises hydrothermal liquefaction of the biomass provided in step A), and wherein said product stream comprises bio-oil, and wherein said at least one by-product stream comprises biomass residues and / or biomass waste;C) subjecting said at least one by-product stream to anaerobic digestion to obtain biogas;D) optionally upgrading said biogas to obtain upgraded biogas;E) subjecting said biogas, optionally upgraded according to step D), to hydrogen production to obtain hydrogen; andF) subjecting the product stream to catalytic hydrotreatment to obtain renewable hydrocarbons, wherein at least a part of the hydrogen produced in step E) is utilized for the hydrotreatment and wherein said renewable hydrocarbons comprise a bio-naphtha fraction.

2. The process of claim 1, wherein in step A) the biomass is of vegetable origin, preferably comprising or being derived from oil palms, soybeans, rapeseed, jatropha, and macauba palm, and / or of animal origin, preferably comprising or being derived from animal fat, livestock-related products like tallow, fish fat, or food waste.

3. The process of one or more of claims 1-2, wherein step C) is replaced by step Ca) comprising the substeps C1), C2a), and C3a):C1) providing at least one feedstock for biogas production, preferably selected from agricultural and crop residues, animal manure, organic fractions of industrial and municipal solid waste, and sewage or wastewater sludge, more preferably selected from agricultural and crop residues, e.g., from rice, and animal manure;C2a) mixing said at least one by-product stream with said at least one feedstock for biogas production; and C3a) subjecting the feedstock mixture of C2a) to anaerobic digestion to obtain biogas; or wherein step C) is replaced by step Cb) comprising the substeps C1), C2b), and C3b):C1) providing at least one feedstock for biogas production, preferably selected from agricultural and crop residues, animal manure, organic fractions of industrial and municipal solid waste, and sewage or wastewater sludge, more preferably selected from agricultural and crop residues, e.g., from rice, and animal manure;C2b) optionally mixing at least two of said at least one feedstocks for biogas production; andC3b) subjecting the at least one feedstock provided in C1) and / or the feedstock mixture of C2b) to anaerobic digestion to obtain biogas.

4. The process of one or more of claims 1-3, wherein in step C) the anaerobic digestion is performed in a biodigester.

5. The process of one or more of claims 1-4, wherein in step D) the upgrading includes water scrubbing, amine gas treatment, pressure swing adsorption, and / or membrane separation techniques.

6. The process of one or more of claims 1-5, wherein in step E) hydrogen production is carried out by hydrocarbon reforming and comprises the substeps E1), E2), and E3)E1) steam reforming to obtain a first gas stream comprising hydrogen, carbon monoxide, and carbon dioxide;E2) water-gas shift reaction of the first gas stream of E1) to obtain a second gas stream comprising hydrogen and carbon dioxide; andE3) purification of the second gas stream of E2), preferably by pressure swing adsorption, to obtain a third gas stream consisting essentially of hydrogen; or hydrogen production is carried out by hydrocarbon pyrolysis and comprises the substeps E4), E5), and E6):E4) hydrocarbon decomposition to obtain a first gas stream comprising hydrogen;E5) processing of solid carbon, optionally carbon separation, post-treatment, and / or carbon purification, to obtain a carbon stream comprising solid carbon; andE6) purification of the first gas stream of E4), preferably by pressure swing adsorption, to obtain a second gas stream consisting essentially of hydrogen.

7. The process of one or more of claims 1-6, wherein in step F) for the catalytic hydrotreatment, at least a part of the hydrogen needed is provided by the hydrogen produced in step E) and / or the renewable hydrocarbons obtained in step F) comprise one or more of renewable diesel, renewable jet fuel, bio-naph- tha, and / or bio-Ci -4-HC fractions, preferably they comprise a bio-naphtha fraction.

8. The process of one or more of claims 1-7, additionally comprising step G)G) separating the renewable hydrocarbons into different fractions, preferably to obtain at least a separate naphtha fraction.

9. The process of one or more of claims 1-8, additionally comprising step H)H) subjecting the renewable hydrocarbons, preferably the naphtha fraction, to isomerization, preferably to form iso-paraffins.

10. The process of one or more of claims 1-9, additionally comprising step J)J) blending the naphtha fraction of the renewable hydrocarbons with at least one fuel, e.g., with gasoline, to obtain a fuel blend with improved characteristics, or subjecting the naphtha fraction of the renewable hydrocarbons to steam cracking to obtain olefins.11 . The process of one or more of claims 1-10, the process further comprising step K)K) controlling the hydrogen production. and wherein preferably step K) comprises the substepsK1) determining the hydrogen demand of step F) (H-dem)',K2) determining the amount of hydrogen obtainable from step E) carried out with biogas derived from said by-product stream via step C) and optional step D) (H-obtl) and determining the amount of hydrogen obtainable from step E) carried out with biogas obtained from said further biogas feedstocks via step C) and optional step D) (H-obt2) and determining the amount of hydrogen obtainable from step E) carried out with said hydrocarbons obtained from step F) (H-obt3)', andK3) controlling supply means for providing said biogas from steps C) and optional step D) to step E) and controlling supply means for providing said hydrocarbons from step F) to step E), such that a total amount of hydrogen is provided by step E) that is sufficient to meet the hydrogen demand of step F) as determined in substep K1) and preferably such that the amount of said hydrocarbons from step F) used in step E) is minimized, wherein preferably step K3) further comprises the substeps of determining the difference H-diff = (H-obt1 + H-obt2) - (H-dem) and if H-diff > 0, controlling the supply means for providing said hydrocarbons from step F) to step E) such that no hydrocarbons from step F) are passed to step E), and if H-diff < 0, controlling the supply means such that hydrocarbons from step F) are passed to step E) such that H-obt3 > -(H-diff).

12. A system for producing renewable hydrocarbons from biomass according to the processes described herein, the system comprisingI) a biomass conversion unit for receiving biomass and processing said biomass into a product stream and into at least one by-product stream;II) a biogas plant, connected and arranged downstream to unit I), for receiving at least one by-product stream from unit I), for producing biogas from said at least one by-product stream via anaerobic digestion, and optionally for upgrading said biogas to upgraded bio-gas;III) a hydrogen production unit, connected and arranged downstream to unit II), for receiving said optionally upgraded biogas, from unit II) and for producing hydrogen from said optionally upgraded biogas; andIV) a bio-oil refinery unit, connected and arranged downstream to units I) and III), for receiving said product stream from unit I) and said hydrogen from unit III) and for producing renewable hydrocarbons from said product stream and said hydrogen via catalytic hydrotreatment.

13. The system according to claim 12, wherein the biogas plant comprises the subunits 11 A) and I IB)11 A) mixing unit, connected and arranged downstream to unit I), for receiving at least one by-product stream from unit I) and for mixing it with at least one feedstock for biogas production, preferably selected from agricultural and crop residues and animal manure; andI IB) anaerobic digestion unit, connected and arranged downstream to unit 11 A), for receiving the feedstock mixture from unit IIA) and for subjecting said feedstock mixture to anaerobic digestion to obtain biogas.

14. The system according to one or more of claims 12-13, wherein the hydrogen production unit comprises, preferably consists of, a reforming unit that comprises the subunits I II A), I IIB), and IIIC):IIIA) steam reforming unit or partial oxidation unit or autothermal reforming unit, connected and arranged downstream to unit II), for reforming hydrocarbons, preferably methane, to obtain a first gas stream comprising hydrogen, carbon monoxide, and carbon dioxide;II IB) water-gas shift unit, connected and arranged downstream to unit IIIA), for performing the water-gas shift reaction for the first gas stream from unit IIIA) to obtain a second gas stream comprising hydrogen and carbon dioxide; andIIIC) purification unit, connected and arranged downstream to unit II IB), for purifying the second gas stream from unit II IB), preferably by pressure swing adsorption, to obtain a third gas stream consisting essentially of hydrogen; or wherein the hydrogen production unit comprises, preferably consists of, a pyrolysis unit that comprises the subunits HID), HIE), and lllF):HID) hydrocarbon decomposition unit, connected and arranged downstream to unit II), for decomposing methane to obtain a first gas stream comprising hydrogen;HIE) solid processing unit, connected and arranged downstream to unit HID), for processing solid carbon, optionally comprising a carbon separation unit, carbon post-treatment unit, and / or a carbon purification unit, to obtain a carbon stream comprising, preferably consisting essentially of, solid carbon; andII IF) purification unit, connected and arranged downstream to unit HID), for purifying the first gas stream from unit HID), preferably by pressure swing adsorption, to obtain a second gas stream consisting essentially of hydrogen.

15. The system according to one or more of claims 12-14, additionally comprising unit V):V) fractionation unit, connected and arranged downstream to unit IV) for separating the renewable hydrocarbons into different fractions, preferably to obtain at least a separate naphtha fraction.

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