Process and apparatus for producing hydrocarbons from solid renewable feedstocks with reduced co2 footprint

Abstract

The present application relates to a process and an installation for producing hydrocarbon products from a solid renewable feedstock, wherein in a thermal decomposition section (e.g. pyrolysis section) for treating the solid renewable feedstock, a pyrolysis off-gas stream and a pyrolysis oil stream are produced, and wherein after hydroprocessing of the pyrolysis oil in a hydroprocessing section, a hydrogen-rich gas stream and a hydrocarbon-comprising off-gas stream are produced. A part of the hydrogen-rich gas stream is used in the hydroprocessing section as a recycle gas stream for producing said hydrocarbon products, such as naphtha and diesel, another part can be used for hydrogen production in a hydrogen production unit, while the off-gas stream is used together with the pyrolysis off-gas stream in the hydrogen production unit. The produced hydrogen gas (i.e. make-up hydrogen gas) is used in the hydroprocessing section.

Description

TECHNICAL FIELD

[0001] The present invention relates to a process and apparatus for producing a hydrocarbon product boiling in the range of transportation fuels, in particular any one of the diesel fuel boiling range, the jet fuel boiling range and the naphtha boiling range, from a solid renewable feedstock, such as a lignocellulosic biomass, e.g. by thermal decomposition, such as pyrolysis, thereby producing a first off-gas stream, such as a pyrolysis off-gas, and a liquid oil, such as a pyrolysis oil. The liquid oil is upgraded by hydroprocessing and separation, thereby producing said hydrocarbon product, while the first off-gas stream is used, together with a second off-gas stream from said hydroprocessing and separation, for producing hydrogen in a hydrogen production unit. At least part of the hydrogen from the hydrogen production unit is used for said hydroprocessing, while the produced naphtha can be upgraded to valuable products, such as gasoline. BACKGROUND

[0002] There is an increasing interest in producing hydrocarbons, such as diesel, jet fuel and naphtha, from renewable feedstocks by hydroprocessing, such as hydroprocessing. In general, hydroprocessing of renewable feedstocks, feedstocks rich in, for example, oxygenates, including vegetable oils and others, requires a large consumption of hydrogen. Some renewable feedstocks also contain nitrogen. Removal of nitrogen also requires hydrogen. In order to produce such a large amount of hydrogen, the requirements for the hydrocarbon feedstock, e.g. natural gas, as raw material and fuel are very high. However, this also increases the CO2 footprint.

[0003] There is also an increasing interest in producing hydrocarbons, in particular hydrocarbon fuels, such as diesel and gasoline (transportation fuels), from solid renewable feedstocks, such as lignocellulosic biomass, by pyrolysis and subsequent hydroprocessing. Pyrolysis produces a pyrolysis oil stream and a pyrolysis off-gas, which is usually flared to the atmosphere.

[0004] US 8492600 discloses a self-sustaining process for producing high quality liquid fuels from biomass, wherein the biomass is subjected to hydro- pyrolysis in a reactor vessel containing molecular hydrogen and a deoxygenation catalyst to produce a partially deoxygenated hydro- pyrolysis liquid that is hydrogenated using a hydroconversion catalyst to produce a substantially fully deoxygenated hydrocarbon liquid and a gas mixture comprising CO and light hydrocarbon gases (C1-C3). The gas mixture is reformed in a steam reformer to produce reformed molecular hydrogen, which is then introduced into the reactor vessel for hydro- pyrolysis of the biomass. The deoxygenated hydrocarbon liquid product is further separated to produce diesel fuel, gasoline or a blended component of diesel and gasoline fuels.

[0005] US 8853475 discloses a process for producing a renewable hydrocarbon fuel. The process includes providing a lignocellulosic material to a pyrolysis zone to produce a stream including a pyrolysis oil, providing the pyrolysis oil stream to a refining zone to produce a refined stream, providing at least a portion of the refined stream to a reforming zone to produce a stream containing hydrogen, providing at least a portion of the hydrogen stream to the refining zone; and recovering the renewable hydrocarbon fuel from the refined stream.

[0006] EP 2814916 A discloses a system for processing a carbonaceous feedstock using the following units: a pyrolysis kiln for pyrolyzing the carbonaceous feedstock, the kiln operating in a slow pyrolysis process in which the carbonaceous feedstock is pyrolyzed for a period of time so as to produce a predominantly gaseous output fraction; a steam reformer located downstream of the kiln to which combustion gases from the pyrolysis kiln are fed; a water scrubber located downstream of the steam reformer in the direction of gas flow; a methanation stage and a CO2 scrubbing stage.

[0007] EP 3347438 A1 discloses a process for producing liquid hydrocarbon products from a biomass feedstock containing solid lignocellulosic material, the process comprising the steps of: a) contacting the feedstock with a first hydropyrolysis catalyst composition and molecular hydrogen in a first hydropyrolysis reactor vessel to produce a product stream comprising a partially deoxygenated hydropyrolysis product, H2O, H2, CO2, CO, C1-C3 gases, coke, and catalyst fines; b) removing said coke and catalyst fines from the product stream; c) hydroconversion of the partially deoxygenated hydropyrolysis product in the presence of one or more hydroconversion catalysts and H2O, CO2, CO, H2, and C1-C3 gases produced in step a) in a hydroconversion reactor vessel to produce a vapor phase product comprising a substantially fully deoxygenated hydrocarbon product, H2O, CO, CO2, and C1-C3 gases, wherein one or more of the first hydropyrolysis catalyst and the hydroconversion catalysts are prepared by a method comprising combining a porous support with one or more catalytically active metals selected from Groups VI and VIII of the Periodic Table of Elements. The vapor phase can be condensed to provide a fully deoxygenated C4+ hydrocarbon liquid and a gas phase comprising H2O, CO, CO2, and C1-C3 gases, which are reformed and shifted to produce hydrogen.

[0008] Similarly, EP 3164472 A1 describes a process for producing liquid hydrocarbon products from a biomass feedstock containing solid lignocellulosic material, comprising using a hydropyrolysis reactor in the presence of a catalyst and hydrogen; thereby producing a product stream comprising a partially deoxygenated hydropyrolysis product, H2O, H2, CO2, CO, C1-C3 gases, coke, and catalyst fines; and after removal of the coke and catalyst fines, processing the product stream in a catalytic hydroconversion reactor, thereby producing a vapor phase product comprising a substantially fully deoxygenated hydrocarbon product, H2O, CO, CO2, hydrogen, and C1-C3 gases. The process further comprises condensing the vapor phase to provide a liquid phase product comprising a substantially fully deoxygenated C4+ hydrocarbon liquid and an aqueous material, and a gas phase product comprising H2O, CO, CO2, and C1-C3 gases, which are reformed and subjected to a water gas process to produce hydrogen.

[0009] US 8324438 discloses a process for producing at least one mixed fuel from a) a paraffin-rich component produced from glycerides and free fatty acids in feedstocks such as vegetable and animal oils, and b) a cyclics-rich component produced from biomass-derived pyrolysis oil. Hydrogen produced in a steam reforming zone is used in the process.

[0010] WO 2015 / 101713 Al describes the integration of pyrolysis, hydroprocessing and hydrogen production by directing pyrolysis off-gas together with off-gas from hydroprocessing to a hydrogen production plant. The off-gas from hydroprocessing into the hydrogen production plant is an H2-rich stream from a separator, e.g. an amine scrubber, and it is used to remove H2S / CO / CO2 from the H2-rich stream. The thus cleaned H2-rich stream is then fed to the hydrogen production plant. This citation does not mention at least the provision of hydrogen from off-gas from production further downstream to the hydrogen production plant. SUMMARY

[0011] The integration of the hydroprocessing stage with a dedicated hydrogen production unit is very important for minimizing carbon dioxide emissions, but in order to reduce such emissions, a significant reduction in the consumption of natural gas, which is typically used as hydrocarbon feed in the hydrogen production unit, is required. While the above integration reduces the overall consumption of hydrogen, and thus of natural gas, it is still desirable to be able to replace a substantial or all of the natural gas used in the hydrogen production unit. However, replacing the natural gas used for hydrogen production requires sacrificing naphtha produced in the hydroprocessing, as it is used as hydrocarbon feed in the hydrogen production unit, thus impairing the potential use of naphtha for gasoline or petrochemical production.

[0012] We have found that, in addition to reducing the overall consumption of hydrogen, it is now possible to integrate a thermal decomposition section, such as a pyrolysis section, and a hydroprocessing section, as well as downstream separation sections, with a hydrogen production unit, and to minimize the energy consumption of the entire process / plant, i.e. the plant comprising said pyrolysis, hydroprocessing / separation and hydrogen production units, mainly by minimizing or eliminating the consumption of natural gas for the hydrogen required for the production of renewable feedstocks, thus substantially reducing the carbon dioxide footprint of the plant.

[0013] Thus, in a first aspect, the present application provides a process for producing a hydrocarbon product, the process comprising the steps of:

[0014] i) passing a solid renewable feedstock through a thermal decomposition section, such as a pyrolysis section, such as a fast pyrolysis section, for producing: a first off-gas stream comprising hydrocarbons, such as a pyrolysis off-gas stream, and a liquid oil stream, such as a pyrolysis oil stream;

[0015] ii) passing the liquid oil stream through a hydroprocessing section to produce a main hydroprocessing stream;

[0016] iii) Direct the main hydrotreating stream into the separation section for production:

[0017] Water flow

[0018] Hydrogen-rich gas flow

[0019] Including the second tail gas stream of hydrocarbons,

[0020] And the hydrocarbon products that boil at temperatures above 50°C;

[0021] iv) Allow the hydrogen-rich gas stream to enter the hydrogenation processing section;

[0022] v) Allow the first tail gas stream from step i) and / or the second tail gas stream from step iii) to enter the hydrogen production unit to produce a supplementary hydrogen stream;

[0023] vi) Allow the supplementary hydrogen stream to enter the hydrogenation processing section;

[0024] In step iii), the separation section includes:

[0025] iii-1) The main hydrotreating stream is fed into a separator, preferably a cold separator, to produce

[0026] The aqueous stream, the hydrogen-rich gas stream, and the heavy hydrocarbon stream;

[0027] iii-2) Allow the heavy hydrocarbon stream to enter the fractionation section to produce the second tail gas stream and the hydrocarbon products;

[0028] as well as

[0029] Before step v), the second exhaust gas flow from step iii) enters the separation unit to remove H2S.

[0030] In one embodiment, the separation unit is at least one of an amine absorption unit, an alkaline scrubber, and a sulfur absorption unit.

[0031] Therefore, compared to the prior art, with this invention, the H2-rich stream from step iii) can be fed to the hydroprocessing stage “unpurified,” i.e., without the removal of, for example, H2S. Instead, H2S is removed from the second tail gas in the fractionation stage, which is a much smaller stream than the aforementioned H2-rich stream, thus enabling much smaller separation units, such as much smaller amine washing, thereby simplifying integration in the process and reducing capital and operating expenses. Furthermore, the H2-rich stream represents the sulfur source in the hydroprocessing stage, particularly in hydrodeoxygenation (HDO), by keeping the HDO catalyst in a sulfidated form. This significantly reduces the external addition of sulfur agents. Suitablely, nickel-molybdenum catalysts for HDO are provided, as in the applicant’s co-pending patent application EP 20162755.1 (WO 2021180808).

[0032] Therefore, in one embodiment, the hydrogen-rich gas stream (in step iii) does not undergo a separation stage for the removal of H2S and / or CO2, and optionally also for the removal of NH3 and / or CO, before entering the hydrotreating section, particularly before entering the first catalytic hydrotreating unit therein. The first catalytic hydrotreating unit is suitable for HDO. All or part of the H2-rich stream is allowed to enter the hydrotreating section.

[0033] As used herein, the term "section," such as "hydroprocessing section," refers to a physical section comprising units or combinations of units for performing one or more steps and / or sub-steps to produce the main hydroprocessing stream, as can be seen from the description below.

[0034] As used herein, the term "hydrogen production unit" refers to a hydrogen production section. Therefore, a hydrogen production unit also refers to a physical section comprising a unit or combination of units that performs one or more steps and / or sub-steps during the production of supplemental hydrogen streams, as can be seen from the description below.

[0035] It should be understood that the hydrogen stream produced in the hydrogen production unit is referred to as the supplementary hydrogen stream.

[0036] It should be understood that the first exhaust gas stream and the liquid oil stream originate from the thermal decomposition of solid renewable feedstock. The first exhaust gas stream (from step i) is fed into the hydrogen processing unit (in step v) and separated from the liquid oil stream that has been upgraded in the hydroprocessing (step ii) and separation stages (step iii). Therefore, the first exhaust gas is not discharged as part of or as a result of liquid oil upgrading. This results in a simpler process because the first exhaust gas is discharged early in the process and used for hydrogen production.

[0037] As used herein, the term "thermal decomposition" should be broadly applied to any decomposition process in which a material is partially decomposed at elevated temperatures (typically 250°C to 800°C or even 1000°C) in the presence of substoichiometric amounts of oxygen (or even in the absence of oxygen). The products are typically a combined stream of liquids and gases, along with a certain amount of solid carbon. The term should be interpreted to include processes known as pyrolysis and hydrothermal liquefaction, both in the presence and absence of a catalyst.

[0038] In one implementation, the pyrolysis section is a pyrolysis section, such as a rapid pyrolysis section as further defined below, thereby producing the first tail gas as a pyrolysis tail gas stream and the liquid oil stream as a pyrolysis oil stream. Therefore, when the pyrolysis section is a pyrolysis section, the first tail gas is also referred to as the pyrolysis tail gas, and the liquid oil stream is referred to as the pyrolysis oil stream. Thus, after condensation, the pyrolysis oil is upgraded in the hydroprocessing and separation sections (steps ii and iii).

[0039] For the purposes of this invention, the pyrolysis section produces two main streams: a pyrolysis tail gas stream and a pyrolysis oil stream. The pyrolysis section can be in the form of a fluidized bed, a transport bed, or a circulating fluidized bed, as is well known in the art. For example, the pyrolysis section may include a pyrolyzer unit (pyrolysis reactor), a cyclone separator for removing particulate solids such as coke, and a cooling unit for thereby producing the pyrolysis tail gas stream and the pyrolysis oil stream (i.e., condensed pyrolysis oil). The pyrolysis tail gas stream comprises light hydrocarbons such as C1-C4 hydrocarbons, CO, and CO2. The pyrolysis oil stream, also known as bio-oil, is a liquid substance rich in molecular blends, typically composed of more than 200 different compounds, including aldehydes, ketones, and / or other compounds, such as furfural with a carbonyl group, produced by the depolymerization of products processed in the pyrolysis.

[0040] For the purposes of this invention, the pyrolysis section is preferably fast pyrolysis, also referred to in the art as rapid pyrolysis. Fast pyrolysis refers to the thermal decomposition of a solid renewable feedstock in the absence of oxygen, at a temperature in the range of 350-650°C (e.g., about 500°C) and a reaction time of 10 seconds or less (e.g., 5 seconds or less, e.g., about 2 seconds). For example, fast pyrolysis can be carried out by autothermal operation, such as in a fluidized bed reactor. The latter is also known as autothermal pyrolysis, characterized by the use of air, optionally an inert gas or a recirculated gas, as the fluidizing gas. Thus, the partial oxidation of the pyrolysis compounds produced in the pyrolysis reactor (autothermal reactor) provides energy for the pyrolysis while improving heat transfer. For more information on autothermal pyrolysis, see Robert Brown's "Heterodoxy in Fast Pyrolysis of Biomass":

[0041] https: / / dx.doi.org / 10.1021 / acs.energyfuels.0c03512

[0042] Therefore, it should be understood that, for the purposes of this invention, the use of self-heating pyrolysis, i.e., self-heating operation, is a specific implementation of rapid pyrolysis.

[0043] Several types of fast pyrolysis exist when catalysts are used. Sometimes, acidic catalysts are used in the pyrolysis reactor to upgrade the pyrolysis steam; this technique is called catalytic fast pyrolysis, which can be operated both in-situ (with the catalyst located within the pyrolysis reactor) and out-of-situ (with the catalyst placed in a separate reactor). The use of catalysts transfers the advantage of oxygen removal, thus helping to stabilize the pyrolysis oil and making it easier for hydroprocessing. Furthermore, increased selectivity for desired pyrolysis oil compounds can be achieved.

[0044] In some cases, hydrogen is added to catalytic pyrolysis, which is called reactive catalytic fast pyrolysis. If catalytic pyrolysis is carried out at high hydrogen pressure (approximately >5 barg), it is usually called catalytic hydropyrolysis.

[0045] In one implementation, the pyrolysis stage is a rapid pyrolysis carried out in the absence of a catalyst and hydrogen; that is, the rapid pyrolysis stage is not catalytic rapid pyrolysis, hydropyrolysis, or catalytic hydropyrolysis. This makes the process simpler and more economical.

[0046] In one embodiment, the pyrolysis tail gas stream comprises CO, CO2, and light hydrocarbons such as C1-C4, and optionally also includes H2S.

[0047] In one implementation, the pyrolysis stage is hydrothermal liquefaction. Hydrothermal liquefaction refers to the thermochemical conversion of biomass into liquid fuel by treating it in a hot, pressurized water environment for a sufficient time, thereby breaking down the solid biopolymer structure primarily into liquid components. Typical hydrothermal processing conditions are temperatures in the range of 250°C–375°C and operating pressures in the range of 40 bar–220 bar. Compared to pyrolysis (e.g., fast pyrolysis), this technology offers advantages such as lower operating temperatures, higher energy efficiency, and lower tar yield. For detailed information on biomass hydrothermal liquefaction, see, for example, Golakota et al., “A review of hydrothermal liquefaction of biomass”, Renewable and Sustainable Energy Reviews, Vol. 81, Part 1, January 2018, pp. 1378–1392.

[0048] According to the present invention, by using a stream separately taken from the separation section, such as the second tail gas stream containing hydrocarbons (in step iii), and the first tail gas stream (e.g., the pyrolysis tail gas (in step i), the pyrolysis section for producing hydrocarbon products and the hydrogenation and separation section are integrated with the hydrogen production unit in the whole method or equipment, thereby greatly reducing the consumption of natural gas used as feed and fuel in the method, or even eliminating the use of natural gas altogether.

[0049] All types of pyrolysis produce pyrolysis tail gas containing hydrocarbons, which are also used as feedstock for hydrogen production units, limiting the amount of naphtha required to completely replace natural gas. Therefore, valuable naphtha is not necessarily used for hydrogen production, and other low-value tail gas streams from the pyrolysis unit are utilized.

[0050] Therefore, the present invention can also reduce carbon dioxide emissions, fully utilize pyrolysis tail gas, better utilize solid renewable raw materials, and obtain higher naphtha yield, i.e., hydrocarbon products boiling within the naphtha boiling range.

[0051] In one embodiment, the hydrogen-rich gas stream (in step iii) comprises 50% vol. of H2 or more light hydrocarbons, such as C1-C4 hydrocarbons, and optionally also includes H2S and NH3, CO and CO2.

[0052] In one embodiment, the second exhaust gas stream comprises light hydrocarbons in the form of C1-C4 hydrocarbons, H2, CO, CO2, and optionally H2S.

[0053] In one embodiment, the hydrocarbon product boiling above 50°C is a hydrocarbon product that boils at least in one of the diesel fuel boiling range, the jet fuel boiling range, and the naphtha boiling range.

[0054] According to the invention, prior to step v), the second tail gas stream from step iii) enters a separation unit, preferably at least one of an amine absorption unit, an alkaline scrubber, and a sulfur adsorption unit, to remove H2S. Therefore, the resulting gas stream entering the hydrogen production unit contains light hydrocarbons, such as C1-C4 hydrocarbons, H2, NH3, CO, and CO2, but contains no H2S or only a small amount of H2S. The second tail gas stream after passing through the separation unit and its derived gas streams contain hydrogen that has not been consumed by the hydrotreating unit in the hydrotreating stage as soluble hydrogen in the hydrocarbon phase, and are suitable for use as part of the feed to the hydrogen production unit, as will be further described below.

[0055] In one embodiment, the method further includes: vii) diverting (step iii) the hydrogen-rich gas stream to form a diverted hydrogen-rich gas stream, and introducing the diverted hydrogen-rich gas stream into the hydrogen production unit. This achieves further integration.

[0056] "Integration" refers to the fluid connection between the pyrolysis section, the hydrogenation processing section, and the subsequent (downstream) separation section and the hydrogen production unit.

[0057] It should be understood that the hydrogen-rich gas stream entering the hydrogenation processing section represents the first recirculated gas stream; optionally, the second tail gas stream passing through the hydrogen production unit after passing through the separation unit represents the second recirculated gas stream; and the diverted hydrogen-rich gas stream passing through the hydrogen production unit represents the third recirculated gas stream.

[0058] In one implementation, step ii) includes the hydrotreating section:

[0059] ii-1) With the addition of hydrogen, the liquid oil stream is passed through the first catalytic hydrotreating unit to produce a first hydrotreating stream, for example, a stream containing C1-C65 hydrocarbons;

[0060] ii-2) With the addition of hydrogen, the first hydrotreating stream is fed into a dewaxing section including a second catalytic hydrotreating unit to produce the main hydrotreating stream.

[0061] It should be understood that the term "in step ii), the hydroprocessing section includes" has the same meaning as the term "step ii) includes". The same interpretation applies to any of the similar wording used in the above or below embodiments.

[0062] Optionally, the method includes using one or more additional catalytic hydrotreating units, such as a third catalytic hydrotreating unit or a cracking section, with the addition of hydrogen. For example, it can be understood that a hydrocracking unit may be appropriately used when hydrocarbon products need to be boiled in the jet fuel range, for example, before the resulting first hydrotreating stream is fed to the dewaxing section.

[0063] In one particular embodiment, between steps ii-1) and ii-2), the method further includes feeding a first hydrotreating stream into a separator, such as a high-pressure or low-pressure separator, to remove H2S, NH3, and H2O, thereby producing the first hydrotreating stream, and optionally also producing a vapor stream and a recirculated oil stream.

[0064] The first hydrotreating stream from the first catalytic hydrotreating unit typically contains impurities, particularly H2S, NH3, CO, and CO2, which can be detrimental to the catalyst used in the subsequent dewaxing stage. When the method operates in the so-called acid mode, the catalyst in the dewaxing stage is an alkali metal catalyst resistant to impurities, thus avoiding the need for a separator. When operating in the so-called sweet mode, the catalyst in the dewaxing stage is a noble metal catalyst sensitive to impurities, therefore requiring the use of a separator.

[0065] In one embodiment, prior to step ii-1, i.e., before introducing the liquid oil into the first catalytic unit, such as a hydrodeoxygenation (HDO) unit, with the addition of hydrogen, the liquid oil is stabilized by introducing it into the catalytic unit with the addition of hydrogen. The term "stabilization" refers to the conversion of carbonyl groups present in the liquid oil compound, such as those in aldehydes, ketones, and acids, into alcohols. For example, this stabilization step can be carried out using a NiMo-based catalyst, as described in Shumeico et al., "Efficient one-stage bio-oil upgrading over sulfide catalysts," ACSSustainable Chem. Eng. 2020, 8, 15149-15167. Preferably, a catalyst system as described in the applicant's co-pending European patent application 21152117.4 is used. As used herein, this stabilization step is included in the hydroprocessing stage ii).

[0066] According to the present invention, in step iii), the separation section includes the following sub-steps:

[0067] iii-1) The main hydrotreating stream is fed into a separator, preferably a cold separator, to produce the aqueous stream, the hydrogen-rich stream, and the heavy hydrocarbon stream;

[0068] iii-2) Allow the heavy hydrocarbon stream to enter a fractionation section, such as a stripping section, to produce the second tail gas stream and the hydrocarbon products, such as hydrocarbon products boiling in at least one of the boiling ranges of diesel fuel, jet fuel, and naphtha.

[0069] In one embodiment, the heavy hydrocarbon stream comprises C5-C30 hydrocarbons, H2, CO, and CO2.

[0070] In one embodiment, in step vi), a supplementary hydrogen flow is introduced into at least one of the following:

[0071] The first catalytic hydrogenation treatment unit;

[0072] The separator between steps ii-1) and ii-2), for example, a high-pressure stripper;

[0073] Second catalytic hydrogenation unit;

[0074] It may also optionally include additional catalytic hydrogenation processing units, such as a third catalytic hydrogenation processing unit.

[0075] In one implementation, the hydrogen-rich gas stream from step iii) is introduced into the first catalytic hydrogenation unit of the hydrogenation processing section.

[0076] It should be understood that the hydrogen added to steps ii), particularly steps ii-1), ii-2), and optionally to the intermediate steps (i.e., allowing the first hydrogenation process stream to enter the separator to remove H2S and NH3), primarily comes from the supplementary hydrogen stream and the hydrogen-rich stream. This makes it possible to reduce or eliminate the need for an external hydrogen source to provide the required hydrogen in this method.

[0077] In one implementation, the separation section in step iii) also produces an LPG stream, and the method further includes feeding the LPG stream into a hydrogen production unit.

[0078] As used in this article, "LPG" refers to liquid petroleum gas (also known as liquefied petroleum gas), which is a gaseous mixture that mainly contains propane and butane, i.e., C3-C4; LPG may also contain i-C3, i-C4 and unsaturated C3-C4 such as C4 olefins.

[0079] Optionally, natural gas is also used as part of the hydrocarbon feedstock in the hydrogen production unit to assist in hydrogen production. While trace amounts of natural gas may be optionally used, the first tail gas from the separation section in step iii) (e.g., pyrolysis tail gas, second tail gas, and optionally LPG) is used as the main part of the hydrocarbon feedstock, or even as the entire hydrocarbon feedstock, i.e., as supplementary gas required by the hydrogen production unit. Therefore, the valuable naphtha being produced is not used for hydrogen production, but can be upgraded to high-quality gasoline or used for other purposes.

[0080] It should also be understood that the hydrocarbon products, i.e. the products produced using solid renewable feedstocks according to the method of the present invention, represent so-called green products or renewable products; therefore, the diesel product is renewable diesel, the jet fuel is renewable jet fuel, and the naphtha is renewable naphtha.

[0081] In one embodiment, the hydrogen production unit includes subjecting a first tail gas stream, a second tail gas stream, and optionally an LPG stream to the following treatments: cleaning in a cleaning unit, preferably a sulfur-chlorine metal absorption or catalytic unit; optionally pre-reforming in a pre-reforming unit; catalytic steam methane reforming in a steam reforming unit; water-gas shift conversion in a water-gas shift unit; optionally removing carbon dioxide in a CO2 separator unit; and optionally purifying hydrogen in a hydrogen purification unit.

[0082] Therefore, in one particular embodiment, the hydrogen production unit includes treating a first tail gas stream, such as a pyrolysis tail gas stream, a second tail gas stream, and optionally an LPG stream, by: cleaning in a cleaning unit, preferably a sulfur-chlorine metal absorption or catalytic unit; optionally, pre-reforming in a pre-reforming unit; catalytic steam methane reforming in a steam reforming unit; water-gas shift conversion in a water-gas shift unit; and removal of carbon dioxide in a CO2 separator unit. In its particular embodiment, the hydrogen production unit does not have a hydrogen purification unit. Therefore, from the CO2 removal section, not only is a CO2-rich stream containing hydrocarbons, hydrogen, and / or CO produced, but also a hydrogen stream. Suitably, the hydrogen stream is a stream containing 95 vol.% or more, for example 98 vol.% or more of hydrogen, i.e., having a hydrogen purity higher than 95 vol.%, with the balance being trace amounts of carbonaceous compounds CH4, CO, CO2, and inert gases N2 and Ar. Therefore, the hydrogen purification unit in the hydrogen production unit can be omitted, thereby reducing the size of the equipment, while the resulting supplemental hydrogen still possesses the purity suitable for use in the hydrogenation process. Simultaneously, the carbon produced in this method is removed as carbon dioxide in the CO2 separator unit. The carbon dioxide can then be captured and transported, for example, through sequestration in geological structures, further reducing CO2 emissions into the atmosphere and thus further reducing the CO2 footprint of the method and equipment.

[0083] In another specific embodiment, the first tail gas stream, such as a pyrolysis tail gas stream, the second tail gas stream, and optionally the LPG stream, are preheated in a flame heater prior to the pre-reforming or catalytic steam reforming, and a portion of the supplementary hydrogen stream is introduced into the flame heater. Thus, the hydrogen stream is used as hydrogen fuel, further reducing carbon emissions because the heat required to burn, for example, natural gas in the flame heater to provide steam reforming is minimized.

[0084] In another specific embodiment, hydrogen purification is performed. Therefore, the hydrogen production unit includes treating a first tail gas stream, such as a pyrolysis tail gas stream, a second tail gas stream, and optionally an LPG stream, by: cleaning in a cleaning unit, preferably a sulfur-chlorine metal absorption or catalytic unit; optionally pre-reforming in a pre-reforming unit; catalytic steam methane reforming in a steam reforming unit; water-gas shift conversion in a water-gas shift unit; optionally removing carbon dioxide in a CO2 separator unit; and purifying hydrogen in a hydrogen purification unit.

[0085] In a particular implementation, a second tail gas stream (a second recirculated gas stream) is fed into the cleaning unit. This is an efficient way to utilize available hydrogen in the process, as sulfur-chlorine metal absorption or catalytic units typically require the addition of hydrogen.

[0086] In one implementation, a first tail gas stream (e.g., a pyrolysis tail gas stream), a second tail gas stream, and an optional LPG stream are combined before entering the hydrogen production unit to form a single hydrocarbon feed.

[0087] In one embodiment, the hydrogen-rich gas stream (first recirculation stream) or the split hydrogen-rich gas stream (third recirculation stream) contains hydrogen at a concentration of 50 vol.% or higher (e.g., 70 vol.% or higher), and either stream is passed through a hydrogen purification unit before the hydrogen-rich gas stream (first recirculation stream) is split to form the split hydrogen-rich gas stream (third recirculation stream), or before the hydrogen-rich gas stream enters the hydrogen processing stage, or before the split hydrogen-rich gas stream enters the hydrogen production unit. Preferably, only the split hydrogen-rich gas stream passes through the hydrogen purification unit.

[0088] This allows for a reduction in the size of the steam reformer, thereby minimizing the total capital expenditure of the hydrogen production unit.

[0089] The hydrogen purification unit can be an H2 membrane separation unit or a pressure swing adsorption (PSA) unit.

[0090] While the aforementioned hydrogen purification unit can be a dedicated (separate) unit, in a particular embodiment, the hydrogen purification unit is the hydrogen purification unit of the hydrogen production unit, and the diverted hydrogen-rich gas stream passes through this hydrogen purification unit. This further contributes to the integration of the entire equipment / method (i.e., the section including the thermal decomposition, hydrogenation processing, and separation sections) and the hydrogen production unit, and to higher energy efficiency. Furthermore, it is more advantageous to use the existing hydrogen purification unit of the hydrogen production unit because the requirement for this unit to provide a hydrogen stream with at least 99 vol.% H2 is generally expected, whereas with this invention, the requirement for hydrogen purity is less stringent because the hydrogen is used in the hydrogenation processing section, particularly the first and second catalytic hydrogenation processes, and any additional catalytic hydrogenation processes, such as the third catalytic hydrogenation process.

[0091] In another specific embodiment, the hydrogen purification unit is a pressure swing adsorption (PSA) unit that produces a PSA tail gas stream, which is used as fuel and / or for steam production in the steam reforming unit of the hydrogen production unit and / or in the flame heater of the flame heater ...

[0092] In one embodiment, the steam reforming unit is a convection reformer, preferably comprising one or more snap-fit ​​reforming tubes, such as an HTCR reformer. Snap-on reformers, in which heat for reforming is transferred via both convection and radiation; tubular reformers, i.e., conventional steam methane reformers (SMRs), in which heat for reforming is primarily transferred via radiation in a radiant furnace; autothermal reformers (ATRs), in which hydrocarbon feedstocks are partially oxidized with oxygen and steam, followed by catalytic reforming; electrothermal steam methane reformers (e-SMRs), in which resistance is used to produce heat for catalytic reforming; or combinations thereof. In particular, when using e-SMRs, electricity from green resources, such as wind, hydro, and solar power, can be utilized, thereby further minimizing the CO2 footprint.

[0093] More information on these reformers is provided in this article by direct reference to the applicant’s patents and / or literature. For example, for tubular and autothermal reforming, a review is provided in “Tubular reforming and autothermal reforming of natural gas—an overview of available processes,” Ib Fuel Processing Technology 42(1995)85-107; and EP 0535505, which provides a description of HTCR. For a description of ATR and / or SMR for large-scale hydrogen production, see, for example, the article “Large-scale Hydrogen Production”, Jens R. Rostrup-Nielsen and Thomas Rostrup-Nielsen: https: / / www.topsoe.com / sites / default / files / topsoe_large_scale_hydrogen_produc.pdf. Alternatively, for a description of ATR and / or SMR for large-scale hydrogen production, see, for example, the article “Large-scale Hydrogen Production”, Jens R. Rostrup-Nielsen and Thomas Rostrup-Nielsen, CATTECH 6, 150-159 (2002). For a description of e-SMR as a newer technology, refer in particular to the applicant’s WO 2019 / 228797 A1.

[0094] In one embodiment, the catalyst in the steam reforming unit is a reforming catalyst, such as a nickel-based catalyst. In one embodiment, the catalyst in the water-gas shift reaction is any catalyst active for the water-gas shift reaction. The two catalysts may be the same or different. Examples of reforming catalysts are Ni / MgAl2O4, Ni / Al2O3, Ni / CaAl2O4, Ru / MgAl2O4, Rh / MgAl2O4, Ir / MgAl2O4, Mo2C, Wo2C, CeO2, Ni / ZrO2, Ni / MgAl2O3, Ni / CaAl2O3, Ru / MgAl2O3, or Rh / MgAl2O3, noble metals supported on an Al2O3 support, but other catalysts suitable for reforming are also conceivable. The catalytically active material may be Ni, Ru, Rh, Ir, or combinations thereof, while the ceramic coating may be Al2O3, ZrO2, MgAl2O3, CaAl2O3, or combinations thereof, and may be mixed with oxides of Y, Ti, La, or Ce. The reactor temperature can range from 850 to 1300°C. The feed gas pressure can be 15-180 bar, preferably about 25 bar. The steam reforming catalyst is also referred to as a steam methane reforming catalyst or a methane reforming catalyst.

[0095] In one embodiment, before the supplemental hydrogen stream enters the hydroprocessing section, the supplemental hydrogen stream passes through a compressor section, which includes a supplemental compressor and optionally a recirculation compressor. The supplemental compressor also produces a supplemental hydrogen recirculation stream, which is added to the hydrogen production unit, preferably directly to the first tail gas stream (e.g., pyrolysis tail gas stream) and / or the second tail gas stream (second recirculation stream) entering the hydrogen production unit and / or to the cleaning unit of the hydrogen production unit. This enables even better integration because a separate or dedicated compressor is not required to recirculate hydrogen within the hydrogen production unit for, for example, hydrogenation of sulfur in the cleaning unit. In a particular embodiment, before the hydrogen-rich stream (first recirculated gas stream) enters the hydroprocessing section, the hydrogen-rich stream passes through the recirculation compressor, i.e., the recirculation compressor included in the compressor section. This achieves further integration.

[0096] In one embodiment, the solid renewable raw material is lignocellulosic biomass, including wood products, forestry waste, and agricultural residues. In another embodiment, the solid biomass raw material is municipal waste, particularly its organic portion. For the purposes of this application, the term "municipal waste" is interchangeable with the term "municipal solid waste" and refers to raw materials containing materials of publicly discarded articles, such as mixed municipal waste with waste code 200301 in the European Waste Catalogue. In a particular embodiment, the lignocellulosic biomass is forestry waste and / or agricultural residues and includes biomass derived from plants, including grasses such as natural grasses (grasses derived from natural landscapes), wheat such as wheat straw, oats, rye, reeds, bamboo, sugarcane or sugarcane derivatives such as bagasse, corn, and other grains.

[0097] Any combination of the above has also been envisioned.

[0098] As used herein, the term "lignocellulose biomass" refers to biomass containing cellulose, hemicellulose, and optionally lignin. Lignin, or a significant portion thereof, may have been removed, for example, through a previous bleaching step.

[0099] In one embodiment, step i) further includes passing the solid renewable feedstock through a solid renewable feedstock preparation section, which includes, for example, drying for water removal and / or pulverization for particle size reduction. Any water / moisture in the solid renewable feedstock evaporated, for example, in a pyrolysis section, condenses in the pyrolysis oil stream and is thus present in the process, which may be undesirable. Furthermore, the heat used for water evaporation absorbs the heat required for pyrolysis in other respects. By removing water and providing a smaller particle size in the solid renewable feedstock, the thermal efficiency of the pyrolysis section is improved.

[0100] In one embodiment, the first catalytic hydrotreating unit is hydrodeoxygenation (HDO), the second catalytic hydrotreating unit is hydrodewaxing (HDW), and an additional catalytic hydrotreating unit such as a third catalytic hydrotreating unit is hydrocracking (HCR).

[0101] Typically, liquid oils, such as pyrolysis oils, may contain significant amounts of oxygenated compounds and unsaturated hydrocarbons. During the hydrotreating of this feedstock, oxygen is primarily removed as H₂O, yielding a fuel mainly composed of cycloalkanes and aromatics. This is known as the hydrodeoxygenation (HDO) pathway. Oxygen can also be removed via a decarboxylation pathway, which produces CO₂ instead of H₂O.

[0102] HDO pathway:

[0103] Decarboxylation pathway:

[0104] Furthermore, although decarbonylation typically does not occur in HDO of triglycerides from typical renewable feedstocks, it can occur in HDO processes of pyrolysis oils:

[0105] Decarbonylation pathway: RCH2COH + H2 <-> RCH3 + CO

[0106] Materials that are catalytically active in HDO (as used herein, and may be used interchangeably with the term hydrotreating HDT) typically include active metals (alkali sulfide metals such as nickel, cobalt, tungsten and / or molybdenum, but may also be elemental noble metals such as platinum and / or palladium) and refractory supports (such as alumina, silica or titanium dioxide, or combinations thereof).

[0107] HDT conditions include a temperature range of 250–400 °C, a pressure range of 30–150 bar, and a liquid hourly space velocity (LHSV) range of 0.1–2, optionally combined with cooling via intermediates quenched with cold hydrogen, feed, or product.

[0108] Materials with catalytic activity in hydrodewaxing (HDW) typically include active metals (elemental noble metals such as platinum and / or palladium or sulfide alkali metals such as nickel, cobalt, tungsten and / or molybdenum), acidic supports (typically molecular sieves exhibiting high shape selectivity and having topological structures such as MOR, FER, MRE, MWW, AEL, TON and MTT), and refractory supports (e.g. alumina, silica or titanium dioxide, or combinations thereof).

[0109] Isomerization conditions include temperatures in the range of 250–400 °C, pressures in the range of 20–100 bar, and liquid hourly space velocities (LHSV) in the range of 0.5–8.

[0110] Materials exhibiting catalytic activity in hydrocracking (HCR) share similar properties with those exhibiting catalytic activity in isomerization, and typically include active metals (elemental noble metals such as platinum and / or palladium or sulfide alkali metals such as nickel, cobalt, tungsten, and / or molybdenum), acidic supports (typically molecular sieves exhibiting high cracking activity and possessing specific topological structures, such as MFI, BEA, and FAU), and refractory supports (e.g., alumina, silica, or titanium dioxide, or combinations thereof). Differences in the catalytic activity of isomerized materials are often due to the nature of the acidic support, which can have different structures (even amorphous silica-alumina) or different acidity, for example, due to the silica:alumina ratio.

[0111] Hydrocracking (HCR) conditions include temperatures ranging from 250 to 400 °C, pressures ranging from 30 to 150 bar, and liquid hourly space velocities (LHSV) ranging from 0.5 to 8, optionally accompanied by intercooling via quenching with cold hydrogen, feed, or product.

[0112] Other types of hydrotreating have also been envisioned, such as hydrodearomatization (HDA). Catalytically active materials in HDA typically include active metals (usually elemental noble metals such as platinum and / or palladium, but also alkali sulfide metals such as nickel, cobalt, tungsten, and / or molybdenum) and refractory supports (e.g., amorphous silica-alumina, alumina, silica, or titanium dioxide, or combinations thereof).

[0113] The conditions for hydrodearomatization include a temperature in the range of 200-350 °C, a pressure in the range of 20-100 bar, and a liquid hourly space velocity (LHSV) in the range of 0.5-8.

[0114] In a second aspect, the present invention is an apparatus for producing hydrocarbon products, i.e., process equipment, comprising:

[0115] - A pyrolysis section, such as a pyrolysis section, is arranged to receive solid renewable feedstock for producing a first tail gas stream, such as a pyrolysis tail gas stream, comprising hydrocarbons, and a liquid oil stream, such as a pyrolysis oil stream.

[0116] - The hydrotreating section is arranged to receive the liquid oil stream and the compressed hydrogen-rich gas feed stream to produce the main hydrotreating stream;

[0117] - Separation section, arranged to receive the main hydrotreating stream to produce an aqueous stream boiling at above 50°C, a hydrogen-rich stream, a second tail stream containing hydrocarbons, and the hydrocarbon products;

[0118] - A separation unit for removing H2S (preferably at least one of an amine absorption unit, an alkaline scrubber, and a desulfurizing agent unit) is arranged to receive the second tail gas stream;

[0119] - Hydrogen production unit (HPU), arranged to receive the first tail gas flow and / or the second tail gas flow to produce a supplementary hydrogen flow;

[0120] - Compressor section, arranged to receive at least a portion of the hydrogen-rich gas flow and the supplementary hydrogen flow produced in the HPU, for generating the compressed hydrogen-rich gas flow and the supplementary hydrogen recirculation flow;

[0121] - A conduit for allowing the first tail gas flow to enter the HPU;

[0122] - A pipeline for allowing the hydrogen-rich gas flow to enter the compressor section, wherein there is no separation unit upstream of the hydrogen processing section for removing H2S and / or CO2 from the hydrogen-rich gas flow, and optionally also for removing NH3 and / or CO;

[0123] - Piping used to allow the supplemental hydrogen flow from the HPU into the compressor section;

[0124] - Optionally, a conduit for recirculating the supplemental hydrogen recirculation stream back to the HPU.

[0125] -Optional means for diverting the hydrogen-rich gas flow to form a diverted hydrogen-rich gas flow and a conduit for allowing the diverted hydrogen-rich gas flow to enter the HPU.

[0126] Any embodiment and related benefits of the first aspect of the invention may be used in conjunction with the second aspect of the invention, or vice versa.

[0127] Brief description of the attached figures

[0128] The accompanying drawings illustrate a schematic flowchart of the entire method / apparatus according to a specific embodiment of the present invention, i.e., an integrated method / apparatus. Detailed Implementation Plan

[0129] Referring to the accompanying drawings, a block flow diagram of the entire method / equipment 10 is shown, wherein a solid renewable raw material 11, such as lignocellulosic biomass, is fed into a pyrolysis section shown here as pyrolysis section 105, thereby producing a pyrolysis oil stream 12 and a first tail gas stream as a pyrolysis tail gas stream 13. Pyrolysis section 105 includes a feed preparation section for, for example, drying to reduce particle size, a rapid pyrolysis unit, and downstream separation units, such as a cyclone separator and a cooling unit (neither of these units is shown here), thereby producing the pyrolysis oil stream 12 and the pyrolysis tail gas stream 13. The pyrolysis oil stream 12 is fed into a hydrotreating section 110. This section includes a feed preparation section and a reactor section, including HDO, HDW, and optional HCR units, to produce the main hydrotreating stream 14, which then enters a separation section 120, producing the following streams: an aqueous (water) stream 16; a hydrogen-rich stream 18, preferably having 50% vol. or more of H2, light hydrocarbons, H2S, CO, and CO2; a second tail stream 20, which includes hydrocarbons, such as light hydrocarbon streams, and also includes NH3, CO, CO2, and H2S, and optionally includes hydrogen that was not consumed as soluble hydrogen in the hydrocarbon phase in the hydrotreating unit; and hydrocarbon products in the form of renewable diesel 22, renewable jet fuel 24, and renewable naphtha 26. The hydrogen-rich stream 18 is not subjected to a separation stage for the removal of H2S and / or CO2, and optionally also for the removal of NH3 and / or CO, before entering the hydrotreating section. The hydrogen-rich gas stream 18 (first recirculation stream 28) used in the hydroprocessing section 110 is split to form the split hydrogen-rich gas stream 30 (third recirculation stream) used in the hydrogen production unit 140. A second tail gas stream 20, much smaller than the hydrogen-rich gas stream 18, from the separation section 120 enters the H2S separation unit 130 to remove H2S, thereby forming a treated second tail gas stream 32 (second recirculation stream), which is then used together with the pyrolysis tail gas stream 13 as the hydrocarbon feed for the hydrogen production unit 140.

[0130] The hydrogen production unit 140 includes a first section 142, which includes a cleaning unit, such as a sulfur-chlorine metal absorption or catalytic unit, one or more pre-reformer units, a steam reforming unit (e.g., a convection reformer (HTCR unit) or an electrically heated steam reformer (e-SMR)), a water-gas shift unit, and a CO2 separator unit (e.g., an amine absorber), as is known in the field of hydrogen production; none of these units are shown here. An optional hydrogen purification unit, such as a PSA unit 144, is provided to further enrich the gas and produce a supplementary hydrogen stream 36. This PSA unit 144 is also used to purify the split hydrogen-rich stream 30. The tail gas 38 (PSA tail gas) from the PSA unit is used for hydrogen production. The fuels in the unit, such as those used as fuel for the HTCR unit, and more particularly as fuel for the HTCR unit burner, and fuel used in the hydroprocessing section 110. In addition to the pyrolysis tail gas 13, another hydrocarbon feed produced in this method, such as the LPG stream 34 generated in the separation section 120, can be used as supplementary gas for steam reforming in the hydrogen production unit 140. Therefore, instead of using natural gas (from an external source) as supplementary gas, and / or the potentially valuable naphtha stream 26, the pyrolysis tail gas 13, the second tail gas 20 or the treated second tail gas 32, and optionally the LPG stream 34 are used as hydrocarbon feeds in the hydrogen production unit 140.

[0131] The first recirculation stream 28 enters the compressor section 150, which includes a recirculation compressor and a supplementary gas compressor (not shown). The first recirculation stream 28 and the supplementary hydrogen stream 36 are compressed by the recirculation compressor and the supplementary compressor, respectively, and are used to add hydrogen as stream 40 to the hydrogen processing section 110. The hydrogen stream 42 (supplementary hydrogen recirculation stream) from the supplementary compressor is recirculated to the hydrogen production unit 140.

Claims

1. A method for producing hydrocarbon products, the method comprising the following steps: i) Passing solid renewable feedstock through a pyrolysis section to produce: a first tail gas stream containing hydrocarbons and a liquid oil stream; ii) Pass the liquid oil stream through the hydroprocessing section to produce the main hydroprocessing stream; iii) The main hydrotreating stream is fed to the separation section for production: Water flow Hydrogen-rich gas flow The second tail gas stream contains hydrocarbons. And the hydrocarbon product, which boils at a temperature above 50°C; iv) The hydrogen-rich gas stream is delivered to the hydrogenation processing section; v) Send the first tail gas stream from step i) and / or the second tail gas stream from step iii) to the hydrogen production unit to produce a supplementary hydrogen stream; vi) The supplementary hydrogen stream is sent to the hydrotreating section; In step iii), the separation section includes: iii-1) The main hydrotreating stream is fed to a separator to produce the aqueous stream, the hydrogen-rich stream, and the heavy hydrocarbon stream; iii-2) The heavy hydrocarbon stream is fed to the fractionation section to produce the second tail gas stream and the hydrocarbon products; as well as Prior to step v), the second tail gas flow from step iii) is passed through a separation unit to remove H2S; and Before being sent to the hydrotreating section, the hydrogen-rich gas stream in step iii) does not undergo a separation stage for removing H2S and / or CO2.

2. The method according to claim 1, wherein the separation unit is at least one of an amine absorption unit, an alkaline scrubber, and a sulfur absorption unit.

3. The method according to claim 1 or 2, wherein the hydrogen-rich gas stream in step iii) does not undergo a separation stage for further removal of NH3 and / or CO before being sent to the hydrotreating section.

4. The method according to claim 3, wherein the hydrogen-rich gas stream in step iii) does not undergo a separation stage for further removal of NH3 and / or CO before being sent to the first catalytic hydrogenation unit in the hydrogenation processing section.

5. The method according to claim 1 or 2, wherein the pyrolysis section is a pyrolysis section, thereby producing the first tail gas flow as a pyrolysis tail gas flow and the liquid oil flow as a pyrolysis oil flow.

6. The method according to claim 1 or 2, wherein the thermal decomposition stage is hydrothermal liquefaction.

7. The method according to claim 5, wherein the pyrolysis section is a rapid pyrolysis section.

8. The method according to claim 1 or 2, wherein the method further comprises: vii) The hydrogen-rich gas stream is split to form a split hydrogen-rich gas stream, and the split hydrogen-rich gas stream is sent to the hydrogen production unit.

9. The method according to claim 1 or 2, wherein in step ii), the hydrotreating section comprises: ii-1) Passing the liquid oil stream through a first catalytic hydrotreating unit with the addition of hydrogen to produce a first hydrotreating stream; ii-2) With the addition of hydrogen, the first hydrotreating stream is fed to a dewaxing section including a second catalytic hydrotreating unit to produce the main hydrotreating stream; as well as Between steps ii-1) and ii-2), the method further includes feeding the first hydrotreating stream to a separator to remove H2S, NH3 and H2O, thereby producing the first hydrotreating stream, and also producing a steam stream and a recirculated oil stream.

10. The method according to claim 9, wherein the separator is a high-pressure or low-pressure separator.

11. The method of claim 9, wherein in step vi), the supplemental hydrogen flow is delivered to at least one of: The first catalytic hydrogenation treatment unit; The separator between steps ii-1) and ii-2); Second catalytic hydrogenation unit; And other additional catalytic hydrogenation processing units.

12. The method according to claim 11, wherein the separator is a high-pressure stripper.

13. The method of claim 11, wherein the additional catalytic hydrogenation unit is a third catalytic hydrogenation unit.

14. The method according to claim 1 or 2, wherein the separation section in step iii) further produces an LPG stream, and the method further comprises feeding the LPG stream into a hydrogen production unit.

15. The method according to claim 1 or 2, wherein the hydrogen production unit comprises subjecting the first tail gas stream, the second tail gas stream, and the LPG stream to at least one of the following treatments: cleaning in a cleaning unit; pre-reforming in a pre-reforming unit; catalytic steam methane reforming in a steam reforming unit; and water-gas shift conversion in a water-gas shift unit.

16. The method of claim 15, wherein the cleaning unit is a sulfur-chlorine metal absorption or catalytic unit.

17. The method of claim 15, wherein the hydrogen production unit further comprises passing the first tail gas stream, the second tail gas stream, and the LPG stream through a CO2 separator unit for carbon dioxide removal.

18. The method of claim 15, wherein the hydrogen production unit further comprises passing the first tail gas stream, the second tail gas stream, and the LPG stream through a hydrogen purification unit for hydrogen purification.

19. The method of claim 15, wherein the hydrogen production unit further comprises passing the first tail gas stream, the second tail gas stream, and the LPG stream through a carbon dioxide removal unit in a CO2 separator unit and a hydrogen purification unit.

20. The method of claim 8, wherein the hydrogen-rich gas stream or the diverted hydrogen-rich gas stream contains hydrogen at a concentration of 50 vol.% or higher.

21. The method of claim 8, wherein either of the streams is passed through a hydrogen purification unit before the hydrogen-rich gas stream is split to form the split hydrogen-rich gas stream, or before the hydrogen-rich gas stream is sent to the hydrogenation processing stage, or before the split hydrogen-rich gas stream is sent to the hydrogen production unit.

22. The method of claim 21, wherein the hydrogen purification unit is a hydrogen purification unit of the hydrogen production unit, and the diverted hydrogen-rich gas stream is passed through the hydrogen purification unit.

23. The method of claim 22, wherein the hydrogen purification unit is a pressure swing adsorption (PSA) unit, the PSA unit produces a PSA tail gas flow, the PSA tail gas flow being used as fuel in: a steam reforming unit of a hydrogen production unit, and / or a flame heater in a hydrogen production unit, and / or a flame heater in any one of a catalytic hydrotreating unit in a hydrotreating section, a separation unit in a separation section; and / or for steam production; as well as The steam reforming unit is: a convection reformer, a tubular reformer, an autothermal reformer, an electrically heated steam methane reformer, or a combination thereof.

24. The method according to claim 1 or 2, wherein the supplemental hydrogen stream is passed through a compressor section before being delivered to the hydrogenation processing section, the compressor section including a supplemental compressor and a recirculation compressor, the supplemental compressor also generating a hydrogen recirculation stream, the hydrogen recirculation stream being added to the hydrogen production unit and / or to a cleaning unit of the hydrogen production unit.

25. The method of claim 24, wherein the hydrogen recirculation stream is directly added to the first tail gas stream and / or the second tail gas stream entering the hydrogen production unit.

26. The method according to claim 1 or 2, wherein the solid renewable raw material is: - Lignocellulose biomass, including: Wood products, forestry waste and agricultural residues; and / or - Urban waste, its waste code in the European waste catalog is 200301.

27. Equipment for producing hydrocarbon products, including: - The pyrolysis section is arranged to receive solid renewable feedstock to produce a first tail gas stream containing hydrocarbons and a liquid oil stream. - A hydrotreating section, which is arranged to receive the liquid oil stream and the compressed hydrogen-rich gas stream to produce the main hydrotreating stream; - Separation section, which is arranged to receive the main hydrotreating stream to produce an aqueous stream, a hydrogen-rich stream, a second tail stream containing hydrocarbons, and the hydrocarbon products boiling at above 50°C; The separation section includes: - A separator, which is arranged to receive the main hydrotreating stream to produce the aqueous stream, the hydrogen-rich stream and the heavy hydrocarbon stream; - A fractionation section, which is arranged to receive a heavy hydrocarbon stream to produce the second tail gas stream and the hydrocarbon products; - A separation unit for removing H2S is arranged to receive the second exhaust gas stream; - A hydrogen production unit (HPU) is arranged to receive the first tail gas flow and / or the second tail gas flow to produce a supplementary hydrogen flow. - A compressor section, which is arranged to receive at least a portion of the hydrogen-rich gas stream and the supplemental hydrogen stream produced in the HPU, to generate the compressed hydrogen-rich gas stream and the supplemental hydrogen recirculation stream. - A conduit for delivering the first exhaust gas flow to the HPU; - A pipeline for delivering the hydrogen-rich gas stream to the compressor section, wherein there is no separation unit upstream of the hydrogenation processing section for removing H2S and / or CO2 from the hydrogen-rich gas stream, and also for removing NH3 and / or CO; - Piping used to deliver the supplemental hydrogen flow from the HPU to the compressor section.

28. The equipment according to claim 27, wherein the pyrolysis section is a pyrolysis section.

29. The apparatus of claim 27, wherein the separation unit for removing H2S is at least one of an amine absorption unit, an alkaline scrubber, and a sulfur absorption unit.

30. The apparatus of claim 27, wherein the apparatus further comprises a conduit for recirculating the supplemental hydrogen recirculation stream to the HPU.

31. The apparatus of claim 27, wherein the apparatus further comprises means for diverting the hydrogen-rich gas flow to form a diverted hydrogen-rich gas flow and a conduit for delivering the diverted hydrogen-rich gas flow to the HPU.

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