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WO2025144693A1 - Procédé de production de carburant à partir de sources renouvelables et dérivées de pétrole - Google Patents

Procédé de production de carburant à partir de sources renouvelables et dérivées de pétrole Download PDF

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Publication number
WO2025144693A1
WO2025144693A1 PCT/US2024/061193 US2024061193W WO2025144693A1 WO 2025144693 A1 WO2025144693 A1 WO 2025144693A1 US 2024061193 W US2024061193 W US 2024061193W WO 2025144693 A1 WO2025144693 A1 WO 2025144693A1
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WO
WIPO (PCT)
Prior art keywords
oil
renewable
petroleum
hydroisomerization
derived
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Pending
Application number
PCT/US2024/061193
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English (en)
Inventor
Vijay Singh RAJASINGH
Edmundo Steven Van Doesburg
Paolo MUCCIOLI
Nikolaos KALOSPYROS
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Shell Internationale Research Maatschappij BV
Shell USA Inc
Original Assignee
Shell Internationale Research Maatschappij BV
Shell USA Inc
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Shell Internationale Research Maatschappij BV, Shell USA Inc filed Critical Shell Internationale Research Maatschappij BV
Publication of WO2025144693A1 publication Critical patent/WO2025144693A1/fr
Pending legal-status Critical Current
Anticipated expiration legal-status Critical

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Classifications

    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G65/00—Treatment of hydrocarbon oils by two or more hydrotreatment processes only
    • C10G65/02—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only
    • C10G65/12—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only including cracking steps and other hydrotreatment steps
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G3/00—Production of liquid hydrocarbon mixtures from oxygen-containing organic materials, e.g. fatty oils, fatty acids
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G65/00—Treatment of hydrocarbon oils by two or more hydrotreatment processes only
    • C10G65/02—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only
    • C10G65/04—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only including only refining steps
    • C10G65/043—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only including only refining steps at least one step being a change in the structural skeleton
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G65/00—Treatment of hydrocarbon oils by two or more hydrotreatment processes only
    • C10G65/14—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural parallel stages only
    • C10G65/16—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural parallel stages only including only refining steps
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/40—Characteristics of the process deviating from typical ways of processing
    • C10G2300/4056—Retrofitting operations

Definitions

  • Vegetable oils, oils obtained from algae, and animal fats are seen as renewable resources. Also, deconstructed materials, such as pyrolyzed recyclable materials or wood, are seen as potential resources.
  • Renewable materials may comprise materials such as triglycerides with very high molecular mass and high viscosity, which means that using them directly or as a mixture in fuel bases is problematic for modem engines.
  • the hydrocarbon chains that constitute, for example, triglycerides are essentially linear and their length (in terms of number of carbon atoms) is compatible with the hydrocarbons used in/as fuels.
  • Petroleum-derived jet fuels inherently contain both paraffinic and aromatic hydrocarbons.
  • paraffinic hydrocarbons offer the most desirable combustion cleanliness characteristics for jet fuels.
  • Challenges in using paraffinic hydrocarbons from renewable sources include higher boiling point, due to chain length, and higher freeze point. Solutions to these challenges include cracking to reduce chain length and/or isomerization to increase branching to improve cold flow properties.
  • Ziegelaar et al. (WO2023/278531A1, 2023 Jan 5) relates to a process for coprocessing a renewable feed and a petroleum feed by hydrotreating the petroleum feed in a first reaction zone and passing the effluent to a second reaction zone with a renewable feed.
  • the reactions in the first reaction zone are one or more of hydrodesulfurization, hydrodenitrogenation, hydrodemetallization, isomerization, hydrogenation of aromatics, and hydrocracking.
  • the reactions in the second reaction zone are one or more of hydrodeoxygenation, decarboxylation, decarbonylation, isomerization, and hydrogenation of olefins.
  • Rippstein et al. (US 11,377, 603B2, 2022 Jul 5) describes a process for coprocessing petroleum distillates and a bio-feed by hydrotreating the petroleum feed and passing the hydrotreated petroleum feed to a dewaxing bed.
  • the dewaxed stream is processed with the bio-feed through liquid quenching beds to create a mixed stream that is processed in posttreatment beds.
  • FIGs. 1 and 2 are flow diagrams illustrating embodiments of the process of the present invention for hydrotreating a renewable feedstock and isomerizing the hydrotreated renewable oil with a hydrotreated petroleum-derived oil.
  • the present invention provides a process for producing fuel from a renewable feedstock and a petroleum-derived oil.
  • a renewable feedstock is hydrotreated.
  • a hydrotreated petroleum-derived oil is provided.
  • the hydrotreated renewable oil and the hydrotreated petroleum-derived oil are combined.
  • a combined liquid is passed to a hydroisomerization zone.
  • the isomerized effluent preferably has improved cold flow properties.
  • renewable feedstock and the petroleum-derived feedstock are co-processed in a hydrotreater.
  • the percentage of renewable oil feedstock must be maintained at a level generally below 10 wt.% to avoid problems associated with metallurgy of conventional petroleum-derived oil hydrotreater, reaction heat release, process safety, and the like.
  • the inventors have surprisingly discovered that by separately hydrotreating the renewable and petroleum-derived feedstocks and combining isomerisation, capital costs may be reduced for higher percentages of coprocessing, especially when revamping an existing petroleum-derived oil refinery.
  • the process of the present invention is important for the energy transition and can improve the environment by producing low carbon energy and/or chemicals from renewable sources, and, in particular, from degradable waste sources, whilst improving the efficiency of the process.
  • a further challenge for meeting product specifications is that the product component yields change as catalyst activity changes, and/or from start-of-run to end-of-run.
  • the process of the present invention provides flexibility and robustness to allow for feedstock variability, changes in catalyst activity, and/or changes in desired products, while reducing energy consumption, operating costs, and/or carbon footprint. Further, the process of the present invention is more flexible in operating conditions and enables revamp of existing process schemes used for processing petroleum-derived feedstock. [0019] Embodiments of process units for carrying out the method of the present invention are described below and/or illustrated in the drawings. For ease of discussion, additional equipment and process steps that may be used in a process for producing fuel from a renewable feedstock are not shown.
  • the additional equipment and/or process steps may include, for example, without limitation, pre-treaters, heaters, chillers, air coolers, heat exchangers, mixing chambers, valves, pumps, compressors, condensers, quench streams, recycle streams, slip streams, purge streams, reflux streams, and the like.
  • Fig. 1 illustrates one embodiment of the process of the present invention 10.
  • a renewable feedstock 12 is reacted in a hydrotreating zone 14 to produce a hydrotreated renewable oil 16.
  • Hydrogen may be combined with the renewable feedstock 12 stream before it is introduced the hydrotreating zone 14, co-fed with the renewable feedstock 12, or added to the hydrotreating zone 14 independently of the renewable feedstock 12.
  • Hydrogen may be fresh and/or recycled from the reactor effluent and/or another unit in the process and/or produced in a HMU (not shown).
  • the hydrogen may be produced, for example, without limitation, by water electrolysis.
  • the water electrolysis process may be powered by renewable energy (such as solar photovoltaic, wind or hydroelectric power) to generate green hydrogen, nuclear energy or by non-renewable power from other sources (grey hydrogen).
  • the hydrotreated renewable oil 16 is combined with a hydrotreated petroleum- derived oil 26 and passed to a hydroisomerization unit 32.
  • the isomerized effluent is directed to a product recovery zone 34.
  • Various embodiments for the product recovery zone 34 may be considered.
  • the embodiments of the product recovery zone 34 may be comprised of one or more unit operations.
  • the product recovery zone 34 may include a product stripper for stripping entrained and/or dissolved gases from the hydroisomerizaton zone effluent, a naphtha stripper to produce the stripper offgas stream and a naphtha stream, a naphtha stabilizer column, a naphtha rectification column, a naphtha recovery column, an overhead separator, a vacuum fractionator, an atmospheric fractionator, and combinations thereof.
  • the product recovery zone 34 may be as described in WO2023043764 (23 Mar 2023) or WO2023043792 (23 Mar 2023), incorporated by reference herein.
  • the product recovery zone 34 includes one or more product recovery units resulting in desired product streams.
  • renewable feedstock means a feedstock from a renewable source.
  • a renewable source may be animal, vegetable, microbial, and/or bio-derived or mineral-derived waste materials suitable for the production of fuels, fuel components and/or chemical feedstocks.
  • vegetable oils, oils obtained from algae, and animal fats are suitable renewable feedstocks.
  • deconstructed materials, such as pyrolyzed recyclable materials or wood are seen as potential resources.
  • a preferred class of renewable materials are bio-renewable fats and oils comprising triglycerides, diglycerides, monoglycerides, free fatty acids, and/or fatty acid esters derived from bio-renewable fats and oils.
  • fatty acid esters include, but are not limited to, fatty acid methyl esters and fatty acid ethyl esters.
  • the bio-renewable fats and oils include both edible and non-edible fats and oils.
  • bio-renewable fats and oils include, without limitation, algal oil, brown grease, canola oil, carinata oil, castor oil, coconut oil, colza oil, com oil, cottonseed oil, fish oil, hempseed oil, jatropha oil, lard, linseed oil, milk fats, mustard oil, olive oil, palm oil, peanut oil, rapeseed oil, sewage sludge, soy oils, soybean oil, sunflower oil, pongamia oil, tall oil, tall oil fatty acids (TOFA), tallow, used cooking oil, yellow grease, white grease, and combinations thereof.
  • Another preferred class of renewable materials are liquids derived from biomass and waste liquefaction processes.
  • liquefaction processes include, but are not limited to, (hydro)pyrolysis, hydrothermal liquefaction, plastics liquefaction, and combinations thereof.
  • Renewable materials derived from biomass and waste liquefaction processes may be used alone or in combination with bio-renewable fats and oils.
  • the renewable materials to be used as feedstock in the process of the present invention may contain impurities.
  • impurities include, but are not limited to, solids, iron, chloride, phosphorus, alkali metals, alkaline-earth metals, polyethylene, and unsaponifiable compounds. If required, these impurities can be removed from the renewable feedstock before being introduced to the process of the present invention. Methods to remove these impurities are known to the person skilled in the art.
  • the hydrotreated petroleum-derived oil 26 is produced by hydrotreating petroleum- derived hydrocarbons including, without limitation, all fractions from petroleum crude oil, natural gas condensate, tar sands, shale oil, synthetic crude, and combinations thereof.
  • the hydrotreated petroleum-derived oil 26 is provided to the process of the present invention 10 from another process and/or refinery.
  • the process 10 includes a hydrotreater 24 for hydrotreating a petroleum-derived feedstock 22 to produce the hydrotreated petroleum-derived oil 26.
  • renewable feedstock 12 is reacted under hydrotreating conditions sufficient to cause a reaction selected from a hydrotreating reaction including, without limitation, hydrodeoxygenation, hydrodenitrogenation, hydrodesulphurization, hydrodearomatization, hydrogenation, hydrodemetallization, and combinations thereof.
  • petroleum-derived feedstock 22 is reacted under hydrotreating conditions sufficient to cause a reaction selected from a hydrotreating reaction including, without limitation, hydrodenitrogenation, hydrodesulphurization, hydrodearomatization, hydrogenation, hydrodemetallization, and combinations thereof.
  • the reactions in the hydrotreating zones 14, 24 are both preferably catalytic reactions, but each may independently include non-catalytic reactions, such as thermal processing and the like.
  • Each of the hydrotreating zones 14, 24 may independently be single-stage or multi-stage.
  • the hydrotreating zones 14, 24 may independently be operated in a slurry, moving bed, fluidized bed, and/or fixed bed operation.
  • each reactor may have a single catalyst bed or multiple catalyst beds.
  • the hydrotreating zones 14, 24 may be comprised of a single reactor or multiple reactors.
  • the hydrotreating zones 14, 24 may be operated in a co-current flow, counter-current flow, or a combination thereof.
  • the hydro treating zones 14, 24 are each independently operated in a co-current flow.
  • the catalyst may be the same or different throughout the hydrotreating zones 14, 24.
  • the hydrotreating zones 14, 24 may comprise a single catalyst bed or multiple catalyst beds.
  • the catalyst may be the same throughout the single catalyst bed, optionally there is a mixture of catalysts, or different catalysts may be provided in two or more layers in the catalyst bed. In an embodiment of multiple catalyst beds, the catalyst may be same or different for each catalyst bed.
  • the hydrotreating zones 14, 24 independently further comprise a hydrogenation catalyst in advance of the hydrotreating catalyst.
  • the hydrogenation components may be used in bulk metal form, or the metals may be supported on a carrier.
  • Active metals for hydrogenation include catalytically active metals of Group VIII and/or Group VIB, including, without limitation, Ni, Co, Mo, W, and combinations thereof.
  • Suitable carriers include refractory oxides, molecular sieves, and combinations thereof. Examples of suitable refractory oxides include, without limitation, alumina, amorphous silica-alumina, titania, silica, and combinations thereof.
  • Suitable molecular sieves include, without limitation, zeolite Y, zeolite beta, ZSM-5, ZSM-12, ZSM-22, ZSM-23, ZSM-48, SAPO-11, SAPO-41, ferrierite, and combinations thereof.
  • the hydrotreating catalyst may be any catalyst known in the art that is suitable for hydrotreating.
  • Catalyst metals are often in an oxide state when charged to a reactor and preferably activated by reducing or sulphiding the metal oxide.
  • the hydrotreating catalyst comprises catalytically active metals of Group VIII and/or Group VIB, including, without limitation, Pd, Pt, Ni, Co, Mo, W, and combinations thereof.
  • Elydrotreating catalysts are generally more active in a sulphided form as compared to an oxide form of the catalyst.
  • a sulphiding procedure is used to transform the catalyst from a calcined oxide state to an active sulphided state.
  • Catalyst may be pre-sulphided or sulphided in situ. Because renewable feedstocks generally have a low sulphur content, a sulphiding agent is often added to the feed to maintain the catalyst in a sulphided form.
  • the hydrotreating catalyst may be sulphided in-situ or ex-situ.
  • In-situ sulphiding may be achieved by supplying a sulphur source, usually H2S or an H2S precursor (i.e., a compound that easily decomposes into H2S such as, for example, dimethyl disulphide, di-tert- nonyl polysulphide or di-tert-butyl polysulphide) to the hydrotreating catalyst during operation of the process.
  • the sulphur source may be supplied with the feed, the hydrogen stream, or separately.
  • the separation zone 40 has one or more separation units including, for example, without limitation, gas/liquid separators, including hot high- and low-pressure separators, intermediate high- and low-pressure separators, cold highland low-pressure separators, high- and low-pressure strippers, integrated strippers, and combinations thereof.
  • gas/liquid separators including hot high- and low-pressure separators, intermediate high- and low-pressure separators, cold highland low-pressure separators, high- and low-pressure strippers, integrated strippers, and combinations thereof.
  • Integrated strippers include strippers that are integrated with hot highland low-pressure separators, intermediate high- and low-pressure separators, cold high- and low-pressure separators.
  • hot means that the hot-separator is operated at a temperature lower than a preceding reactor in the hydro treating zone 14 temperature, suitably sufficiently above water dew point (e.g., >10°C, preferably >20°C, above the water dew point) and sufficiently greater than salt deposition temperatures (e.g., >10°C, preferably >20°C, above the salt deposition temperature), while intermediate- and cold-separators are at a reduced temperature relative to the preceding reactor in the hydrotreating zone 14.
  • a coldseparator is suitably at a temperature that can be achieved via an air cooler.
  • a hot-separator preferably operates at a temperature in a range from 150 to 250°C, while a cold-separator preferably operates at a temperature in a range from 40 to 120°C.
  • An intermediate temperature will be understood to mean any temperature between the temperature of a hot- or coldseparator.
  • the process of the present invention is particularly advantageous for efficiently and effectively revamping an existing petroleum refinery.
  • a challenge for revamping an existing hydrodesulfurization unit is that the typical hydrodesulfurization unit is produced using a metallurgy that is not compatible with renewable feedstocks at a concentration of greater than about 10 wt.%.
  • Another challenge is that, when the renewable feedstock content is greater than about 10 wt.%., the heat of reaction is typically too high for conventional petroleum hydrotreaters. Accordingly, additional catalyst beds and increased quenching are typically required. It is difficult to change the number of catalyst beds in an existing petroleum hydrotreater.
  • the process of the present invention 10 solves the problem by separately hydrotreating the renewable feedstock 12 and the petroleum-derived feedstock 22 in independent hydrotreating zones 14, 24 and then combining the hydrotreated oils 16, 26 for co-processing in a hydroisomerization unit.
  • a stripper preferably an existing stripper from an existing refinery, more preferably an existing low-pressure stripper, is a preferred location for combining the hydrotreated renewable oil 16 and the hydrotreated petroleum- derived oil 26.
  • a portion of the hydrotreated renewable oil 16 from one or more separator units may be returned to a hydro treating zone 14, for example, as a quench stream (not shown) or as a diluent (not shown) of feedstock 12.
  • the volumetric ratio of diluent to fresh renewable feedstock 12 is preferably in a range of from 1: 1 to 30:1.
  • the quench stream is used to control temperature in the hydrotreating zone 14 and therefore typically cooled using, for example, an air cooler (not shown) or a heat exchanger (not shown).
  • One or more quench streams may be added between catalyst beds/zones in the hydrotreating zone 14.
  • hydrotreated renewable oil 16 and the hydrotreated petroleum-derived oil 26 (with or without a separation step) is passed to a hydroisomenzation zone 32 under hydroisomerization conditions to cause a hydroisomerization reaction.
  • Isomerization has the effect of improving cold flow properties of the hydrotreated renewable oil 16 and the hydrotreated petroleum-derived oil 26.
  • the hydroisomerization catalyst may be any suitable catalyst composition known to those skilled in the art.
  • the hydroisomerization catalyst comprises a Group VIII metal. More preferably, the hydroisomerization catalyst further comprises a zeolitic material.
  • the hydroisomerization catalyst may further comprise a binder and/or carrier, such as, without limitation, silica, alumina, silica-alumina, and combinations thereof.
  • the Group VIII metal is selected from the group consisting of platinum, palladium, nickel, and combinations thereof.
  • the hydroisomerization preferably includes a Group VI metal, preferably Mo or W.
  • the zeolitic matenal is preferably selected from the group consisting of Beta, COK- 7, EU-1, EU-2, EU-11, IZM-1, MCM-22, NU-10, ZSM-5, ZSM-12, ZSM-22, ZSM-23, ZSM- 30, ZSM-35, ZSM-48, ZSM-50, ZSM-57, and combinations thereof.
  • the catalyst may be the same or different throughout the hydroisomerization zone 32.
  • the hydroisomerization zone 32 may comprise a single catalyst bed or multiple catalyst beds.
  • the catalyst may be the same throughout the single catalyst bed, optionally there is a mixture of catalysts, or different catalysts may be provided in two or more layers in the catalyst bed. In an embodiment of multiple catalyst beds, the catalyst may be same or different for each catalyst bed.
  • the hydroisomerization zone 32 is operated in the presence of hydrogen at a pressure in a range of from 1 MPa to 30 MPa and at a temperature in a range of from 260°C to 400°C.
  • the pressure is in a range of from 2 MPa to 17 MPa
  • the temperature is in a range of from 300°C to 380°C.
  • the LHSV is in a range of from 0.2 h' 1 to 4 h' 1 based on the hydrotreated oils 16, 26.
  • the ratio of the hydrogen gas to the combined liquid supplied to the hydroisomerization zone 32 is in a range of from 100 to 1500 normal L (at standard conditions of 0 °C and 1 atm (0. 1 MPa)) per kg of the combined liquid.
  • Hydroisomerization is particularly advantageous for improving the production of kerosene for jet fuel.
  • WABT weighted average bed temperature
  • WABT is a representative temperature, assuming an adiabatic reactor having no loss or gain from its surroundings, for the catalyst bed. Those skilled in that art understand that the temperature profile will typically increase from inlet to outlet.
  • the product recovery zone 34 produces, for example, without limitation, an off-gas stream 36, a naphtha boiling point range stream 42, a kerosene boiling point range 38, a diesel boiling point range stream 44, and/or a heavy fraction 52.
  • the product streams are dependent on the composition of the feedstocks 12, 22 and/or the components and/or the operating conditions of the product recovery zone 34.
  • the hydroisomerization zone 32 optionally includes a hydrofinishing zone (not shown). During the hydroisomerization step and/or depending on the feedstock used, some aromatics and/or trace olefins may be present in the effluent of the hydroisomerization zone.
  • the hydrofinishing components may be used in bulk metal form, or the metals may be supported on a carrier.
  • Active metals for hydrogenation include catalytically active metals of Group VIII and/or Group VIB, including, without limitation, Ni, Co, Mo, W, and combinations thereof.
  • the Group VIII metal is selected from the group consisting of platinum, palladium, nickel, and combinations thereof.
  • Suitable carriers include refractory oxides. Examples of suitable refractory oxides include, without limitation, alumina, amorphous silica-alumina, titania, silica, and combinations thereof. EXAMPLE

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  • Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Engineering & Computer Science (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Organic Chemistry (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)

Abstract

L'invention concerne un procédé de production de carburant à partir d'une charge d'alimentation renouvelable et d'une huile dérivée de pétrole qui consiste à hydroraffiner la charge d'alimentation renouvelable puis à combiner l'huile renouvelable hydroraffinée et l'huile dérivée de pétrole. Un liquide combiné est mis à réagir dans une zone d'hydroisomérisation pour produire un effluent isomérisé.
PCT/US2024/061193 2023-12-27 2024-12-19 Procédé de production de carburant à partir de sources renouvelables et dérivées de pétrole Pending WO2025144693A1 (fr)

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Application Number Priority Date Filing Date Title
IN202311089172 2023-12-27
IN202311089172 2023-12-27
EP24156215.6 2024-02-07
EP24156215 2024-02-07

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US9062258B2 (en) 2006-12-18 2015-06-23 Total Raffinage Marketing Process for hydrotreating a diesel fuel feedstock, hydrotreating unit for the implementation of the said process, and corresponding hydrorefining unit
US10577547B2 (en) 2018-02-27 2020-03-03 Uop Llc Process for producing fuels from a blended biorenewable feed
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WO2023278531A1 (fr) 2021-06-30 2023-01-05 Bp Corporation North America Inc. Co-traitement de charges d'alimentation renouvelables dans le traitement du pétrole
WO2023043764A1 (fr) 2021-09-16 2023-03-23 Shell Usa, Inc. Procédé de production de kérosène et de diesel à partir de sources renouvelables
WO2023043792A1 (fr) 2021-09-16 2023-03-23 Shell Usa, Inc. Procédé de production de kérosène et de diesel à partir de sources renouvelables
WO2023107834A1 (fr) * 2021-12-07 2023-06-15 Shell Usa, Inc. Procédé de production d'un hydrocarbure liquide à partir de sources renouvelables

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