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
  • C10G1/00—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal
  • C10G1/002—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal in combination with oil conversion- or refining processes
• • 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
  • C10G1/00—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal
  • C10G1/10—Production of liquid hydrocarbon mixtures from oil-shale, oil-sand, or non-melting solid carbonaceous or similar materials, e.g. wood, coal from rubber or rubber waste
• • 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
  • C10G31/00—Refining of hydrocarbon oils, in the absence of hydrogen, by methods not otherwise provided for
  • C10G31/08—Refining of hydrocarbon oils, in the absence of hydrogen, by methods not otherwise provided for by treating with water
• • 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
  • C10G31/00—Refining of hydrocarbon oils, in the absence of hydrogen, by methods not otherwise provided for
  • C10G31/09—Refining of hydrocarbon oils, in the absence of hydrogen, by methods not otherwise provided for by filtration
• • 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
  • C10G31/00—Refining of hydrocarbon oils, in the absence of hydrogen, by methods not otherwise provided for
  • C10G31/10—Refining of hydrocarbon oils, in the absence of hydrogen, by methods not otherwise provided for with the aid of centrifugal force
• • 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
  • C10G32/00—Refining of hydrocarbon oils by electric or magnetic means, by irradiation, or by using microorganisms
  • C10G32/02—Refining of hydrocarbon oils by electric or magnetic means, by irradiation, or by using microorganisms by electric or magnetic means
• • 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
  • C10G45/00—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds
  • C10G45/02—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing
  • C10G45/04—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing characterised by the catalyst used
  • C10G45/06—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing characterised by the catalyst used containing nickel or cobalt metal, or compounds thereof
  • C10G45/08—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing characterised by the catalyst used containing nickel or cobalt metal, or compounds thereof in combination with chromium, molybdenum, or tungsten metals, or compounds thereof
• • 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
• • 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
  • C10G67/00—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one process for refining in the absence of hydrogen only
  • C10G67/02—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one process for refining in the absence of hydrogen only plural serial stages only
  • C10G67/04—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one process for refining in the absence of hydrogen only plural serial stages only including solvent extraction as the refining step in the absence of hydrogen
  • C10G67/0454—Solvent desasphalting
• • 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
  • C10G67/00—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one process for refining in the absence of hydrogen only
  • C10G67/02—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one process for refining in the absence of hydrogen only plural serial stages only
  • C10G67/04—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one process for refining in the absence of hydrogen only plural serial stages only including solvent extraction as the refining step in the absence of hydrogen
  • C10G67/0454—Solvent desasphalting
  • C10G67/0463—The hydrotreatment being a hydrorefining
• • 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
  • C10G9/00—Thermal non-catalytic cracking, in the absence of hydrogen, of hydrocarbon oils
  • C10G9/34—Thermal non-catalytic cracking, in the absence of hydrogen, of hydrocarbon oils by direct contact with inert preheated fluids, e.g. with molten metals or salts
  • C10G9/36—Thermal non-catalytic cracking, in the absence of hydrogen, of hydrocarbon oils by direct contact with inert preheated fluids, e.g. with molten metals or salts with heated gases or vapours
• • C—CHEMISTRY; METALLURGY
  • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
  • C10B—DESTRUCTIVE DISTILLATION OF CARBONACEOUS MATERIALS FOR PRODUCTION OF GAS, COKE, TAR, OR SIMILAR MATERIALS
  • C10B53/00—Destructive distillation, specially adapted for particular solid raw materials or solid raw materials in special form
  • C10B53/07—Destructive distillation, specially adapted for particular solid raw materials or solid raw materials in special form of solid raw materials consisting of synthetic polymeric materials, e.g. tyres
• • 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
  • C10G2300/10—Feedstock materials
  • C10G2300/107—Atmospheric residues having a boiling point of at least about 538 °C
• • 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
  • C10G2300/10—Feedstock materials
  • C10G2300/1077—Vacuum residues

Definitions

• the present invention relates to the field of hydroconversion of feeds comprising mainly a heavy fraction of hydrocarbons of fossil origin and a minor fraction of pyrolysis oil of plastics and/or tires and/or solid recovered fuels (CSR). ), loaded with impurities.
• the heavy hydrocarbon fraction is a heavy petroleum load of the atmospheric residue and/or vacuum residue type.
• the present invention relates to a process for treating such a mixed feed in a fixed bed with a view to producing higher quality materials with a lower boiling point, for example for the purposes of producing fuels, or of chemicals, while allowing the capture of impurities from the pyrolysis oil of plastics and/or tires and/or CSR.
• plastics from collection and sorting sectors can undergo a pyrolysis step in order to obtain, among other things, pyrolysis oils.
• plastic pyrolysis oils are generally burned to generate electricity and/or used as fuel in industrial or district heating boilers.
• Solid recovered fuels also called “refuse derived fuel” (RDF), or even “solid recovered fuels” (SRF) according to Anglo-Saxon terminology, are solid non-hazardous waste prepared for recovery. energy, whether they come from household and similar waste, waste from economic activities or construction-demolition waste.
• CSR is generally a mixture of any combustible waste such as scrap tires, food by-products (fats, flours animals, etc.), viscose and wood waste, light fractions from shredders (for example from used vehicles, electrical and electronic equipment (WEEE)), household and commercial waste, residues from the recycling of various types of waste, including certain municipal waste, plastic waste, textiles, wood among others.
• CSRs generally contain plastic waste.
• CSRs are mainly used for energy. They can be used directly as substitutes for fossil fuels in co-incineration installations (coal and lignite thermal power plants, cement plants, lime kilns) or in household waste incineration units, or indirectly in dedicated pyrolysis units.
• CSR pyrolysis oils are generally burned to generate electricity, or even used as fuel in industrial or district heating boilers.
• Pyrolysis oils from plastics and/or tires and/or CSR can also be upgraded, possibly via refining processes, to produce fuels, for example gasoline or diesel, and/or chemicals such as olefins for the production of various polymers in the chemical industry.
• plastic waste, tires or CSR are generally mixtures of several polymers, for example mixtures of polyethylene, polypropylene, polyethylene terephthalate, polyvinyl chloride, polystyrene.
• plastics can contain, in addition to polymers, other compounds, such as plasticizers, pigments, dyes or even residues of polymerization catalysts, as well as other very varied impurities, organic and mineral, coming from the separation operations of sorting centers, an operation whose selectivity cannot be total.
• the oils resulting from pyrolysis thus generally include a lot of diolefins and impurities, in particular metals, silicon, or even halogenated compounds, in particular compounds based on chlorine, heteroelements such as sulfur, oxygen and nitrogen, insolubles, often at high levels and which may be incompatible with certain refining units.
• One way to eliminate these impurities contained in plastic and/or tire and/or CSR pyrolysis oils is to carry out hydrotreatment in the presence of catalysts.
• Application WO2018/055555 proposes for example a global, very general and relatively complex plastic waste recycling process, ranging from the very stage of pyrolysis of plastic waste to a steam cracking stage which makes it possible to produce highly recoverable products in the field of petrochemicals such as olefins and aromatic compounds.
• the process includes, among other things, a step of hydrocracking the liquid phase resulting directly from pyrolysis, preferably in a fixed bed.
• Patent applications FR3107530, FR3113060 and FR3113061 describe processes for treating a plastic pyrolysis oil, comprising, among other things, a selective hydrogenation step of the plastic pyrolysis oil and a fixed bed hydrotreatment of the effluent hydrogen.
• the naphtha cut resulting from a water-specific separation of the hydrotreated effluent followed by fractionation of the separated hydrocarbon stream can be sent to a steam cracker or used as a fuel base.
• the process integrates one or two hydrocracking stages in a fixed bed after the hydrotreatment stage, to minimize the yield of the heavy cut and to maximize the yield of the naphtha cut by transforming the heavy cut at least partly in naphtha cut by hydrocracking, cut generally favored for a steam cracking unit.
• the present invention relates to the field of the recovery of heavy loads of fossil origin that are difficult to recover such as petroleum residues, which generally contain high levels of impurities such as metals, sulfur, nitrogen, Conradson carbon and asphaltenes. , to convert them into lighter products, usable as fuels, for example to produce gasoline, diesel or bunker fuel, or raw materials for petrochemicals.
• the present invention proposes a process for treating a feed comprising a heavy fraction of hydrocarbons of fossil origin having an initial boiling temperature of at least 340°C and a final boiling temperature of at least 340°C. minus 550°C and containing sulfur and nitrogen, and a fraction of pyrolysis oil from plastics and/or tires and/or recovered solid fuels, said fraction of pyrolysis oil constituting less than 50% by weight of said charge, said process comprising: a) a hydrodemetallation step implemented in a fixed bed reaction section comprising at least two permutable reactors, said section being supplied at least by said feed and a gas flow comprising hydrogen, in the presence of at least one hydrodemetallation catalyst, at a temperature between 300 and 500°C, an absolute pressure between 5 MPa and 35 MPa and an hourly volume velocity between 0.1 and 5.0 h -1 , b) a step d hydrotreatment implemented in a reaction section comprising at least one fixed bed reactor, said section being supplied at least by said effluent from
• the inventors have demonstrated that, surprisingly, it was possible to incorporate a minor fraction of pyrolysis oil from plastics and/or tires and/or CSR, loaded with impurities, to a heavy hydrocarbon load of fossil origin, typically an atmospheric residue or a vacuum residue, traditionally treated in a fixed bed hydroconversion process, thus allowing optimized treatment of the two difficult feedstocks by effectively treating the impurities present and converting the feedstocks into recoverable products .
• the present invention thus proposes a process for the hydroconversion of a heavy load of hydrocarbons of fossil origin, in particular of the atmospheric residue and/or vacuum residue type, in a fixed bed, said load including a minor fraction of oil.
• pyrolysis of plastics and/or tires and/or CSR thus allowing the production of basic fuels and other recoverable hydrocarbons and/or feedstocks suitable for a steam cracker for the production of olefins and/or aromatics.
• plastic pyrolysis oil allows a significant increase in the yield of the PI-180°C cut while reducing the yields of heavy cuts.
• One of the essential aspects of the invention lies in the capacity of the fixed bed reactor(s) to at least partially convert the pyrolysis oil into lighter products thanks to the combination of a high temperature and the presence of 'a catalyst that allows the hydrogenation of unsaturated molecules (olefins or aromatics).
• the co-treatment of pyrolysis oil thus makes it possible to improve the yield of certain cuts obtained in the hydrotreated effluent, in particular the gasoline cut.
• Another advantage of the invention is to limit the increase in temperature between the inlet and the outlet of a fixed bed reactor, induced in particular by the heat released by the hydrogenation of the diolefins or olefins contained in particular in the fraction d pyrolysis oil, this heat being partly absorbed by the heavy fraction of hydrocarbons of fossil origin which is treated simultaneously.
• the result is an optimized process that limits the significant use of effluent recycling and/or gaseous and/or liquid cooling flows.
• Another objective of the present invention is to produce, by means of the same process, atmospheric distillates (naphtha, kerosene, diesel), vacuum distillates, marine fuels and/or light gases (C1 to C4).
• bases such as naphtha, kerosene and diesel can be upgraded in refineries for the production of fuels for automobiles and aviation, such as for example premium fuels, jet fuels and gas oils.
• naphtha, kerosene and diesel type bases can be upgraded in a steam cracking unit in order to be able to obtain in particular light olefins which can be used as monomers in the manufacture of polymers.
• naphtha, kerosene and diesel type bases can be upgraded in a fluidized bed catalytic cracking unit (FCC for Fluid Catalytic Cracking according to Anglo-Saxon terminology) or even in a hydrocracking unit.
• FCC Fluid Catalytic Cracking according to Anglo-Saxon terminology
• the vacuum distillate can be upgraded in a hydrocracking unit.
• An advantage of the invention is to propose a process coupling conversion and purification of heavy loads of fossil origin for the production of marine fuels with low sulfur content while efficientlyzing a co-charge of pyrolysis oil.
• the quality requirements for marine fuels are described in the ISO 8217 standard.
• the sulfur specification now focuses on SO International Maritime Reorganization) and results in a recommendation for sulfur content less than or equal to 0.5% by weight outside the Sulfur Emissions Control Areas (ESZs or Emissions Control Areas / ECA in English) in 2020-2025, and less than or equal to 0.1% by weight in the ZCES.
• Another very restrictive recommendation is the sediment content after aging according to ISO 10307-2 (also known as IP390), which must be less than or equal to 0.1% by weight.
• the viscosity of RMG 380 grade bunker fuel oils must respect a viscosity limit lower than 380 cST at 50°C.
• a pyrolysis oil as a co-charge in the treatment of a heavy charge of fossil origin makes it possible in particular to directly obtain a fuel oil meeting the specifications in terms of sulfur, sediments and viscosity, without the need to add a flux. Fluxants are typically added to lower the viscosity of a bunker fuel oil to meet viscosity specifications. It is in fact the presence of the pyrolysis oil, generally lighter in terms of boiling points, which makes it possible to lower the sulfur content and the viscosity to achieve the required specifications.
• the process according to the invention thus makes it possible to directly obtain a bunker fuel oil meeting the required specifications (without the need to add a flux, which is conventionally the case to meet the specifications) while simultaneously having the advantage of being able to valorize a difficult-to-recover feedstock such as a pyrolysis oil and increase the yield of sought-after distillates.
• the method according to the invention comprises at least one step aO) of pretreatment of the pyrolysis oil fraction of plastics and/or tires and/or solid recovered fuels , said pretreatment step being implemented upstream of step a) and comprises an adsorption step and/or a filtration step and/or a centrifugation step and/or an electrostatic separation step and/or a step of washing using an aqueous solution and/or a gas stripping step.
• the fraction of pyrolysis oil constitutes between 1% and 45% by weight of said charge, preferably between 2% and 30% by weight of said charge, preferably between 2% and 25% weight of said load.
• the feed consists of said pyrolysis oil fraction and said heavy hydrocarbon fraction, said pyrolysis oil fraction constituting between 1% and 45% by weight, of preferably between 2% and 30% by weight, more preferably between 2% and 25% by weight of said charge and the heavy fraction of hydrocarbons constituting between 55% and 99% by weight, preferably between 70% and 98% by weight, more preferably between 75% and 98% weight of said load.
• the heavy hydrocarbon fraction is chosen from the list consisting of an atmospheric residue or a vacuum residue resulting from the atmospheric and/or vacuum distillation of a crude oil or an effluent from a thermal conversion, hydrotreatment, hydrocracking or hydroconversion unit, an aromatic cut extracted from a lubricant production unit, a deasphalted oil from a deasphalting unit, a asphalt from a deasphalting unit, a residual fraction from the direct liquefaction of coal, a vacuum distillate from the direct liquefaction of coal, bituminous sands or their derivatives, bituminous shales or their derivatives, oils from parent rock or their derivatives, taken alone or in a mixture.
• the heavy hydrocarbon fraction is a vacuum residue and/or an atmospheric residue.
• the hydrodemetallation catalyst of step a) comprises from 0.5% to 10% by weight of nickel, expressed as nickel oxide NiO relative to the total weight of the catalyst , and from 1% to 30% by weight of molybdenum, expressed as molybdenum oxide MoOa relative to the total weight of the catalyst, on a mineral support chosen from the group consisting of alumina, silica, silica-aluminas, magnesia, clays and mixtures of at least two of these minerals.
• the hydrotreatment catalyst of step b) comprises from 0.5% to 10% by weight of nickel, expressed as nickel oxide NiO relative to the total weight of the catalyst , and from 1% to 30% by weight of molybdenum, expressed as molybdenum oxide MoOa relative to the total weight of the catalyst, on a mineral support chosen from the group consisting of alumina, silica, silica-aluminas, magnesia, clays and mixtures of at least two of these minerals.
• said separation section in step c) comprises means for washing by contact with an aqueous solution.
• separation step c) comprises: c1) a first separation step carried out at a temperature higher than the precipitation temperature of ammonium halides to obtain at least a first gaseous fraction and a liquid effluent, c2) a second separation step, supplied with first gaseous fraction and at least part of the liquid effluent from step c1) and an aqueous solution, said step being carried out at a lower temperature at halide precipitation temperature ammonium to obtain at least a second gaseous fraction, an aqueous effluent and a liquid product.
• the method according to the invention further comprises a step d) of subsequent treatment of at least one liquid product from step c), said step d) comprising at least one step chosen from the list consisting of hydrotreatment, steam cracking, catalytic cracking in a fluidized bed, hydrocracking, deasphalting, extraction of lubricating oils.
• step (a) in step (a), the pyrolysis oil fraction and the heavy hydrocarbon fraction of the feed are mixed beforehand before their introduction into one of said permutable reactors .
• step (a) the pyrolysis oil fraction of the feed is introduced separately from the heavy hydrocarbon fraction into one of said permutable reactors.
• step (a) comprises a step of preheating said heavy hydrocarbon fraction, preferably at a temperature between 280°C and 450°C, and a step of preheating the pyrolysis oil fraction carried out at a temperature lower than that of said heavy hydrocarbon fraction, before introducing the charge into one of said swappable reactors.
• the invention also relates to the product capable of being obtained, and preferably obtained by the process according to the invention.
• Such a product advantageously comprises a silicon content less than or equal to 10 ppm by weight, and/or a chlorine element content less than or equal to 10 ppm by weight relative to the weight of the product.
• the expression “between ... and ...” means that the limit values of the interval are included in the range of values described, unless otherwise specified.
• the different parameter ranges for a given step such as the pressure ranges and the temperature ranges, can be used alone or in combination.
• a range of preferred pressure values can be combined with a range of more preferred temperature values.
• group VIII (or VIIIB) according to the CAS classification corresponds to the metals of columns 8, 9 and 10 according to the new IIIPAC classification.
• the metal content is measured by X-ray fluorescence.
• treatment process refers to a process that includes hydroconversion and hydrotreatment reactions.
• hydroconversion refers to a process whose primary purpose is to reduce the boiling point range of a feedstock, and in which a substantial portion of the feedstock is converted to products with higher boiling point ranges. boiling points lower than those of the original charge. Hydroconversion generally involves the fragmentation of larger hydrocarbon molecules into smaller molecular fragments having a smaller number of carbon atoms and a higher hydrogen to carbon ratio. The reactions carried out during hydroconversion make it possible to reduce the size of hydrocarbon molecules, mainly by cleavage of carbon-carbon bonds, in the presence of hydrogen in order to saturate the cut bonds and the aromatic rings.
• hydroconversion occurs typically involves the formation of hydrocarbon free radicals during fragmentation primarily by thermal cracking, followed by capping of the free radical termini or fragments with hydrogen in the presence of active catalyst sites.
• other reactions typically associated with hydrotreatment can occur, such as, among others, the elimination of sulfur or nitrogen from the feed, or the saturation of olefins, and as defined more broadly below.
• hydrotreating commonly called “HDT” refers to a gentler operation whose main purpose is to remove impurities such as sulfur, nitrogen, oxygen, halides, and traces of metals from the charge, and to saturate olefins and/or stabilize hydrocarbon free radicals by reacting them with hydrogen rather than allowing them to react with themselves.
• the main purpose is not to change the boiling point range of the filler.
• hydrotreatment includes in particular hydrodesulfurization reactions (commonly called “HDS”), hydrodenitrogenation reactions (commonly called “HDN”) and hydrodemetallation reactions (commonly called “H DM”), accompanied by reactions hydrogenation, hydrodeoxygenation (commonly called “HDO”), hydrodearomatization, hydrodechlorination, hydroisomerization, hydrodealkylation, hydrocracking, hydrodeasphalting and carbon reduction Conradson.
• HDS hydrodesulfurization reactions
• HDN hydrodenitrogenation reactions
• H DM hydrodemetallation reactions
• pyrolysis oil means an oil resulting from the pyrolysis of plastics and/or tires and/or CSR, unless otherwise indicated.
• the “heavy hydrocarbon fraction” of the load is referred to as a heavy fraction of hydrocarbons of fossil origin, unless otherwise indicated.
• the charge mainly comprises a heavy fraction of hydrocarbons of fossil origin and a minor fraction of pyrolysis oil from plastics and/or tires and/or CSR.
• the feed consists of said minor fraction of pyrolysis oil of plastics and/or tires and/or CSR, and of a majority heavy fraction of hydrocarbons of fossil origin.
• the process according to the invention is thus specific to the hydroconversion of a mixture of pyrolysis oil of plastics and/or tires and/or low content CSR and a heavy fraction of hydrocarbons of fossil origin .
• the fraction of pyrolysis oil from plastics and/or tires and/or CSR constitutes less than 50% weight of the charge (total weight of the charge), preferably between 1% and 45% weight of the charge, more preferably between 2% and 30% weight of the filler, even more preferably between 2% and 25% weight of the filler, even more preferably between 3% and 20% weight of the filler, and even more preferably between 5% and 20% weight of the load, or even between 5% and 15% weight of the load.
• the charge can consist of these two fractions only: the pyrolysis oil fraction and the heavy hydrocarbon fraction, the sum of the pyrolysis oil fraction and the heavy hydrocarbon fraction forming 100% weight of the charge.
• the heavy fraction of hydrocarbons can constitute, preferably when the charge consists of said heavy fraction hydrocarbons and the pyrolysis oil fraction, between 55% and 99% by weight of the charge, preferably between 70% and 98% by weight of the charge, more preferably between 75% and 98% by weight of the charge, even more preferably between 80% and 97% weight of the load, and even more preferably between 80% and 95% weight of the load, or even between 85% and 95% weight of the load.
• a “plastic pyrolysis oil or tire pyrolysis oil or CSR pyrolysis oil” is an oil, advantageously in liquid form at room temperature, resulting from the pyrolysis of plastics, preferably from plastic waste originating in particular from collection and sorting channels, or from the pyrolysis of used tires or even from the pyrolysis of CSR. It comprises in particular a mixture of hydrocarbon compounds, in particular paraffins, olefins (mono- and/or diolefins), naphthenes and aromatics. At least 80% by weight of these hydrocarbon compounds preferably have a boiling point below 700°C, and preferably below 550°C.
• the pyrolysis oil can comprise up to 70% by weight in paraffins, up to 90% by weight in naphthenes, up to 90% by weight in olefins and up to 90% by weight in olefins.
• % weight of aromatics it being understood that the sum of paraffins, naphthenes, olefins and aromatics is equal to 100% weight of hydrocarbon compounds.
• the pyrolysis oil may include diolefins.
• the diolefin content is commonly determined indirectly as the maleic anhydride index (or MAV for Maleic Anhydrid Value according to Anglo-Saxon terminology).
• the method is based on the Diels-Alder addition reaction between conjugated diolefins and maleic anhydride.
• the method for determining the MAV is described in C. Lôpez-Garcia et al., Near Infrared Monitoring of Low Conjugated Diolefins Content in Hydrotreated FCC Gasoline Streams, Oil & Gas Science and Technology - Rev. IFP, Vol. 62 (2007), No. 1, pp. 57-68.
• the MAV is expressed in mg of maleic anhydride reacted with 1 g of sample (mg/g).
• the MAV varies between 5 and 100 mg/g in pyrolysis oils.
• the density of the pyrolysis oil measured at 15°C according to the ASTM D4052 method, is generally between 0.75 g/cm 3 and 0.99 g/cm 3 , preferably between 0.75 g/cm 3 and 0.95 g/cm 3 .
• the pyrolysis oil can comprise, and most often comprises, additionally impurities such as metals, in particular iron, silicon, halogenated compounds, in particular chlorinated compounds.
• impurities can be present in the pyrolysis oil at high levels, for example up to 500 ppm by weight or even 700 ppm by weight or even 1000 ppm by weight, and even 5000 ppm by weight, of halogen elements (in particular chlorine but also bromine, fluorine, iodine or astatine) provided by halogenated compounds, and generally between 1 and 1000 ppm by weight or between 1 and 700 ppm by weight or even between 1 and 500 ppm by weight of halogen elements.
• halogen elements in particular chlorine but also bromine, fluorine, iodine or astatine
• the oil can include up to 200 ppm by weight, or even 1500 ppm by weight of metallic or semi-metallic elements, and generally between 1 and 200 ppm by weight or between 1 and 1500 ppm by weight of metallic or semi-metallic elements.
• Alkali metals, alkaline earths, transition metals, poor metals and metalloids can be assimilated to contaminants of a metallic nature, called metals or metallic or semi-metallic elements.
• the metals or metallic or semi-metallic elements include silicon, iron or both elements.
• the pyrolysis oil may in particular comprise up to 200 ppm by weight or even 1000 ppm by weight of silicon, and generally between 1 and 200 ppm by weight or between 1 and 1000 ppm by weight or even between 1 and 500 ppm by weight of silicon.
• the pyrolysis oil may in particular comprise up to 50 ppm by weight or even 100 ppm by weight of iron, and generally between 1 and 50 ppm by weight or between 1 and 100 ppm by weight of iron.
• Pyrolysis oil may also include phosphorus, sodium, calcium, potassium and magnesium.
• the pyrolysis oil may also include other impurities such as heteroelements provided in particular by sulfur compounds, oxygenated compounds and/or nitrogen compounds, at contents generally less than 40,000 ppm weight of heteroelements and preferably less than 15,500 ppm weight of heteroelements, and generally between 1 and 40,000 ppm weight of heteroelements or between 1 and 15,500 ppm weight of heteroelements.
• the sulfur compounds are generally present in a content of less than 15,000 ppm by weight and preferably less than 10,000 ppm by weight, and generally between 1 and 15,000 ppm by weight or between 1 and 10,000 ppm by weight of sulfur compounds.
• the oxygenated compounds are generally present in a content of less than 15,000 ppm by weight and preferably less than 10,000 ppm by weight, and generally between 1 and 15,000 ppm by weight or between 1 and 10,000 ppm by weight of oxygenated compounds.
• the nitrogen compounds are generally present in a content of less than 10,000 ppm by weight and preferably less than 5,000 ppm by weight, and generally between 1 and 10,000 ppm by weight or between 1 and 5,000 ppm by weight of nitrogen compounds.
• the pyrolysis oil may also include other impurities like heavy metals such as mercury, arsenic, zinc and lead, e.g. up to 100 ppb wt. or 200 ppb by weight of mercury or arsenic, and generally between 1 and 200 ppb by weight or between 1 and 100 ppb by weight of heavy metals.
• heavy metals such as mercury, arsenic, zinc and lead, e.g. up to 100 ppb wt. or 200 ppb by weight of mercury or arsenic, and generally between 1 and 200 ppb by weight or between 1 and 100 ppb by weight of heavy metals.
• the process according to the invention is particularly well suited to treating a pyrolysis oil loaded with impurities, in combination with a heavy load of hydrocarbons as defined in more detail below.
• loaded with impurities we mean that the pyrolysis oil has the following properties:
• the pyrolysis oil for plastics and/or tires and/or CSR can come from a thermal or catalytic pyrolysis treatment or even be prepared by hydropyrolysis (pyrolysis in the presence of a catalyst and hydrogen).
• the heavy fraction of hydrocarbons of fossil origin of the feed of the process according to the invention is a heavy fraction of hydrocarbons having an initial boiling temperature of at least 340°C and a final boiling temperature of at least 340°C. minus 550°C and containing sulfur and nitrogen.
• its initial boiling temperature is at least 350°C, preferably at least 375°C
• its final boiling temperature is at least 550°C, preferably at least 560°C. C, and even more preferably at least 600°C.
• the heavy hydrocarbon fraction of the feed may comprise, or consist of, atmospheric residues and/or vacuum residues resulting from the atmospheric and/or vacuum distillation of a crude oil.
• the heavy hydrocarbon fraction of the feed may also consist of atmospheric and/or vacuum residues from atmospheric and/or vacuum distillation of effluents from thermal conversion units, hydrotreatment, hydrocracking and/or hydroconversion.
• the heavy hydrocarbon fraction of the feed may also consist of aromatic cuts extracted from a lubricant production unit, deasphalted oils from a deasphalting unit (raffinates from the deasphalting unit), asphalts from a deasphalting unit (residues from the deasphalting unit).
• the heavy hydrocarbon fraction of the feed can also be a residual fraction resulting from the direct liquefaction of coal (an atmospheric residue and/or a vacuum residue resulting for example from the H-Coal® process).
• the heavy hydrocarbon fraction comprises, and may consist of, at least one of the following charges, alone or in mixture: an atmospheric residue or a vacuum residue from atmospheric distillation and/or under vacuum of a crude oil or an effluent coming from a thermal conversion, hydrotreatment, hydrocracking or hydroconversion unit, an aromatic cut extracted from a lubricant production unit, a deasphalted oil from a deasphalting unit, an asphalt from a deasphalting unit, a residual fraction from the direct liquefaction of coal.
• the heavy hydrocarbon fraction that is treated is preferably an atmospheric residue or a vacuum residue, or a mixture of these residues.
• the heavy hydrocarbon fraction of the feed treated according to the invention contains impurities, such as sulfur and nitrogen. It may also contain impurities such as metals, Conradson carbon and asphaltenes, particularly C? which are insoluble in heptane.
• the sulfur content may be greater than or equal to 0.1% by weight, or even greater than or equal to 0.5% or 1% by weight, and may be greater than or equal to 2% by weight.
• the nitrogen content is usually between 1 ppm and 8000 ppm by weight, more generally between 200 ppm and 8000 ppm by weight, for example between 2000 ppm and 8000 ppm by weight.
• the metal contents in particular Ni and V can be greater than or equal to 20 ppm by weight, preferably greater than or equal to 100 ppm by weight.
• the Conradson carbon content can be greater than or equal to 3% by weight, or even at least 5% by weight.
• the Conradson carbon content is defined by the ASTM D482 standard and represents for those skilled in the art a well-known evaluation of the quantity of carbon residue produced after pyrolysis under standard conditions of temperature and pressure.
• the filler of the process according to the invention may further comprise, at a low content, typically between 1% and 20% by weight of the filler, or even between 1% and 10%, a fraction of vegetable and/or animal oil or fat, and/or a hydrocarbon fraction resulting from thermal and/or catalytic conversion processes of lignocellulosic biomass, such as an oil produced from lignocellulosic biomass, according to various liquefaction methods such as liquefaction hydrothermal or pyrolysis, which is then co-treated with the pyrolysis oil of plastics and/or tires and/or CSR and the heavy fraction of hydrocarbons of fossil origin.
• a low content typically between 1% and 20% by weight of the filler, or even between 1% and 10%
• a fraction of vegetable and/or animal oil or fat and/or a hydrocarbon fraction resulting from thermal and/or catalytic conversion processes of lignocellulosic biomass, such as an oil produced from lignocellulosic biomass, according to various liquef
• Oils/fats of plant and/or animal origin contain triglycerides and/or free fatty acids and/or esters.
• Vegetable oils can advantageously be crude or refined, totally or in part, and can be derived from the following plants: rapeseed, sunflower, soya, palm, palm kernel, olive, coconut, jatropha (jatropha), castor, cotton, peanuts, flax, crambe, this list is not exhaustive. Algae or fish oils are also relevant.
• Oils/fats of plant and/or animal origin can be used, for example used cooking oils.
• Animal fats can be chosen from bacon or fats composed of residues from the food industry or from the catering industries.
• lignocellulosic biomass refers to compounds derived from plants or their by-products, and includes constituents selected from the group formed by cellulose, hemicellulose (carbohydrate polymers) and/or lignin (aromatic polymer).
• the feed of the process according to the invention does not include any vegetable and/or animal oil or fat fraction, or any hydrocarbon fraction resulting from thermal and/or catalytic conversion processes of lignocellulosic biomass. such as biomass pyrolysis oil.
• the pyrolysis oil of plastics and/or tires and/or CSR can advantageously be pretreated in at least one optional pretreatment step aO), prior to step a) of hydrodemetallation, to obtain a pretreated pyrolysis oil which feeds step a).
• this optional pretreatment step aO) makes it possible to reduce the quantity of contaminants and solid particles, in particular the quantity of iron and/or silicon and/or chlorine, possibly present in the pyrolysis oil.
• This optional step aO) allows in particular the elimination of sediments which may form due to the unstable nature of pyrolysis oils and/or a compatibility problem between two different charges.
• an optional step aO) of pretreatment of the pyrolysis oil is advantageously carried out in particular when said oil comprises more than 10 ppm by weight, in particular more than 20 ppm by weight, more particularly more than 50 ppm by weight of metallic elements and/ or solid particles, and in particular when said oil comprises more than 5 ppm by weight of silicon, more particularly more than 10 ppm by weight, or even more than 20 ppm by weight of silicon.
• an optional step aO) of pretreatment of the pyrolysis oil is advantageously carried out in particular when said oil comprises more than 10 ppm by weight, in particular more than 20 ppm by weight, more particularly more than 50 ppm by weight of chlorine.
• Said optional pretreatment step aO) can be implemented by any method known to those skilled in the art making it possible to reduce the quantity of contaminants. It may in particular comprise an adsorption step and/or a filtration step and/or a centrifugation step and/or an electrostatic separation step and/or a washing step using an aqueous solution and /or a gas stripping step.
• the optional pretreatment step aO) is advantageously carried out at a temperature between 20 and 400°C, preferably between 40 and 350°C, and at a pressure between 0.15 and 10.0 MPa abs, preferably between 0.2 and 7.0 MPa abs.
• said optional pretreatment step aO) is implemented in an adsorption section operated in the presence of at least one adsorbent.
• the adsorbent can be chosen from a zeolite, activated carbon, clay, silica or alumina.
• Said adsorption section of optional step aO) comprises at least one adsorption column, preferably comprises at least two adsorption columns, preferably between two and four adsorption columns, containing said adsorbent.
• a mode of operation can be an operation called "swing", according to the established Anglo-Saxon term, in which one of the columns is in line, i.e. i.e. in operation, while the other column is in reserve.
• the absorbent of the online column is worn out, this column is isolated while the reserve column is put online, that is to say in operation.
• the spent absorbent can then be regenerated in situ and/or replaced with fresh absorbent so that the column containing it can be put back online once the other column has been isolated.
• Another mode of operation is to have at least two columns operating in series. When the absorbent of the column placed at the top is worn out, this first column is isolated and the spent absorbent is either regenerated in situ or replaced by fresh absorbent. The column is then put back online in last position and so on.
• This operation is called permutable mode, or according to the English term “PRS” for Permutable Reactor System or even “lead and lag” according to the established Anglo-Saxon term.
• the combination of at least two adsorption columns makes it possible to overcome poisoning and/or possible and possibly rapid clogging of the adsorbent under the joint action of metal contaminants, diolefins, gums derived from diolefins and insolubles possibly present in the pyrolysis oil to be treated.
• the presence of at least two adsorption columns facilitates the replacement and/or regeneration of the adsorbent, advantageously without stopping the pretreatment unit, or even the process, thus making it possible to reduce the risks of clogging and therefore avoid stopping the unit due to clogging, controlling costs and limiting adsorbent consumption.
• said optional pretreatment step aO) is implemented in a washing section with an aqueous solution, for example water or an acidic or basic solution.
• This washing section may include equipment making it possible to bring the load into contact with the aqueous solution and to separate the phases so as to obtain the pretreated load on the one hand and the aqueous solution comprising impurities on the other hand.
• this equipment there may for example be a stirred reactor, a decanter, a mixer-decanter and/or a co- or counter-current washing column.
• said optional pretreatment step aO) is implemented by filtration.
• the filtration step removes inorganic solids, sediments and/or fines contained in the oil, including metals, metal oxides and metal chlorides.
• a filter is generally used whose size (for example the diameter or equivalent diameter) of the pores is less than 25 pm, preferably less than or equal to 10 pm, even more preferably less than or equal to 5 pm.
• a filter can be used whose pore size is less than 25 pm but greater than 5 pm.
• a series of filters with different pore sizes can also be used, including a series of filters with decreasing pore sizes in the direction of oil flow. These filter media are well known for industrial uses. Cartridge filters and self-cleaning filters are suitable, for example.
• the dry extract can be measured for example by the Heptane Insolubles test, ASTM Method D-3279. The content of heptane insolubles should be reduced to less than 0.5% by weight, preferably less than 0.1%.
• the pretreatment step aO) by filtration comprises at least one filter whose pore size is less than 10 pm, and preferably greater than 5 pm, followed by an electrostatic precipitation system.
• the pretreatment step aO) by filtration comprises at least one filter whose pore size is less than 10 pm, and preferably greater than 5 pm, followed by a system of filter(s). ) using filter aids such as sand or diatomaceous earth.
• said optional pretreatment step aO) is carried out by centrifugation.
• the pretreatment step aO) comprises centrifugation and filtration.
• said optional pretreatment step aO) is implemented by gas stripping, thus reducing the oxygen content in the oil.
• Gas extraction can remove oxygen (O2) which may be dissolved in the feed thus reducing the likelihood of free radical formation leading to polymerization in downstream stages.
• the process generally involves contacting the oil with an extracting gas (e.g. H2, N2 or a mixture thereof), thereby transferring at least part of the dissolved oxygen from the oil to the gas extraction, followed by the separation of the extraction gas from the oil.
• the volume of extraction gas relative to the volume of oil is generally greater than 1, and preferably at least 3.
• the extraction gas may contain at least 60% (molar percentage) H 2 . Any dissolved H 2 remaining in the feed after the gas extraction step is not a problem, considering the downstream hydrodemetallation/rhydroprocessing.
• the gas extraction step is completed before any (pre)heating of the feed, in order to minimize potential fouling.
• Said optional pretreatment step aO generally comprises one or more, preferably several treatments described above. It may in particular comprise a sequence of a washing step using an aqueous solution and/or an adsorption step, followed by a gas stripping step, followed by a filtration step and/or d a centrifugation step. All these steps are preferably carried out before any (pre)heating of the load.
• Said optional pretreatment step aO) thus makes it possible to obtain a pretreated pyrolysis oil which then feeds the hydrodemetallation step a).
• the process comprises a step a) of hydrodemetallation implemented in a fixed bed reaction section comprising at least two permutable reactors, said section being supplied at least by said feed mainly comprising said heavy fraction of hydrocarbons d fossil origin and a minor fraction of pyrolysis oil, optionally pretreated in step aO), and a gas flow comprising hydrogen, in the presence of at least one hydrodemetallation catalyst, at a temperature between 300 and 500°C, an absolute pressure of between 5 MPa and 35 MPa and an hourly volume velocity of between 0.1 and 5.0 h'1 .
• the pyrolysis oil fractions and heavy hydrocarbon fractions can be introduced in different ways into the hydrodemetallation step.
• the pyrolysis oil fraction can be mixed beforehand with the heavy hydrocarbon fraction of the feed before entering the reaction section of step a) of hydrodemetallation.
• Another variant is the separate injection of the pyrolysis oil fraction and the heavy hydrocarbon fraction into the reaction section of step a).
• This mode of injection may be preferred to avoid any problem linked to a chemical incompatibility between the two fractions (risk of demixing or precipitation of asphaltenes for example), or to avoid possible accelerated clogging of the preheating oven (the high contents of diolefins and olefins in the pyrolysis oil of plastics and/or tires and/or CSR can lead to the formation of gums).
• the feed i.e. mixing or not of the fractions before their introduction into the reaction section of step a) of hydrodemetallation
• the feed, and in particular the heavy hydrocarbon fraction of the feed is generally preheated. at a temperature suitable for hydrodemetallation.
• the preheating of the heavy hydrocarbon fraction is preferably carried out at a temperature between 280°C and 450°C, even more preferably between 300°C and 400°C, and even more preferably between 320°C and 365°C. vs.
• This preheating can also include heating the pyrolysis oil fraction, in particular if said fraction is injected separately from the heavy hydrocarbon fraction, however preferably at a lower temperature than for the heavy hydrocarbon fraction so as to limit the formation of gums and/or coking of preheating equipment (for example ovens and/or heat exchangers) due to the presence of olefins and diolefins in the pyrolysis oil fraction.
• the pyrolysis oil fraction can be preheated to a temperature between ambient temperature, e.g. 15°C, and 350°C, preferably between 100° and 350°C, more preferably between 100°C and 250°C.
• the pyrolysis oil fraction can for example be preheated by an oven or by mixing with a hotter gas flow comprising hydrogen coming from the hydrogen makeup and/or recycled from step c) of the process according to the invention.
• preheating can be carried out after mixing, before or during.
• preheating the mixture of the two fractions is preferably carried out at a temperature between 280°C and 450°C, even more preferably between 300°C and 400°C, and even more preferably between 320°C and 365°C.
• the pyrolysis oil fraction is heated indirectly by mixing with the heavy hydrocarbon fraction (i.e. heat exchange between the two fractions by bringing said two fractions which have different temperatures into contact).
• At least one oven commonly called a preheating oven, may be used, comprising for example at least one heating compartment, and/or tubes in which the load flows, a mixer of the load with H2, any type of suitable heat exchangers, for example tubular or spiral heat exchangers in which the charge flows, etc.
• the feed Before its introduction into the reaction section of step a) of hydrodemetallation, the feed undergoes a pressurization step to be adapted to the pressure operated in the reaction section of step a) of hydrodemetallation, for example at using a suitable pump.
• This pressurization step is preferably carried out before the preheating step.
• the objective of this hydrodemetallation step a) is to reduce the content of impurities, in particular metals, in particular silicon, and halogen (in particular chlorine), and the content of diolefins and olefins which can be derived from the heavy fossil fraction or pyrolysis oil, and thus protect downstream hydrotreatment step b) from deactivation and clogging, hence the concept of guard reactors.
• impurities in particular metals, in particular silicon, and halogen (in particular chlorine)
• diolefins and olefins which can be derived from the heavy fossil fraction or pyrolysis oil
• hydrodemetallation guard reactors are implemented as permutable reactors (“PRS” technology, for “Permutable Reactor System” according to Anglo-Saxon terminology) as described in patent FR2681871.
• swappable reactors we mean a set of at least two reactors of which one of the reactors can be stopped, generally for regeneration or replacement of the catalyst or for maintenance, while the other (or others) is (are) in operation .
• permutable reactors are fixed beds located upstream of the fixed bed hydrotreatment section of step b) and equipped with lines and valves so as to be permuted between them, that is to say for a system with two permutable reactors Ra and Rb, Ra can be upstream of Rb and vice versa.
• Each reactor Ra, Rb can be taken offline so as to change the catalyst without shutting down the rest of the unit.
• This change of catalyst is generally enabled by a conditioning section (set of equipment outside the main high pressure loop).
• the reactor containing the fresh catalyst is then put back online in last position and so on.
• the permutation for changing the catalyst occurs when the catalyst is no longer sufficiently active (metal poisoning and coking) and/or the clogging results in too high a pressure loss.
• step a) of hydrodemetallation hydrodemetallation reactions (commonly called HDM) occur, but also hydrodesulfurization reactions (commonly called H DS), hydrodenitrogenation reactions (commonly called HDN) accompanied by reactions of hydrogenation, hydrodechlorination, hydrodeoxygenation, hydrodearomatization, hydroisomerization, hydrodealkylation, hydrocracking, hydrodeasphalting and carbon reduction Conradson.
• Step a) is called hydrodemetallation because it eliminates the majority of metals in the load.
• the silicon contained in the charge is deposited on the catalyst(s) during this step.
• chlorinated compounds a minor part of which (the mineral part) is deposited on the catalyst while the organic chlorinated compounds are transformed into HCl.
• Step a) of hydrodemetallation in permutable reactors according to the invention can advantageously be carried out at a temperature between 300°C and 500°C, preferably between 350°C and 430°C, and under absolute pressure. between 5 MPa and 35 MPa, preferably between 11 MPa and 26 MPa, preferably between 14 MPa and 20 MPa.
• the temperature is usually adjusted according to the desired level of hydrodemetallation and the targeted treatment duration.
• the temperature is generally adjusted to remove most and preferably all of the metals, including silicon.
• the space velocity of the hydrocarbon load also called hourly volume velocity (liquid hourly space velocity “LHSV” or hourly space velocity “HSV” according to Anglo-Saxon terminology), commonly called WH, and which is defined as being the volumetric flow rate of the feed divided by the total volume of the catalyst, can be included in a range going from 0.1 h -1 to 5 h -1 , preferably from 0.15 h -1 to 3 h -1 , and more preferably from 0.2 h -1 to 2 h -1 .
• hourly volume velocity liquid hourly space velocity “LHSV” or hourly space velocity “HSV” according to Anglo-Saxon terminology
• the quantity of hydrogen mixed with the charge can be between 100 and 5000 normal cubic meters (Nm 3 ) per cubic meter (m 3 ) of liquid charge, preferably between 200 Nm 3 /m 3 and 2000 Nm 3 /m 3 , and more preferably between 300 Nm 3 /m 3 and 1000 Nm 3 /m 3 .
• Step a) of hydrodemetallation in switchable reactors is carried out industrially in at least two reactors in a fixed bed and preferably with a downward flow of liquid.
• Each permutable reactor is a fixed bed reactor having n catalytic beds, n being an integer greater than or equal to 1, each comprising at least one hydrodemetallation catalyst.
• At least one reactor of step a) of hydrodemetallation or of step b) of hydrotreatment, and preferably all reactors, is(are) equipped with a filtration and distribution device, for example a device such as those described in patent applications FR3043339 and FR3051375.
• step a) and/or step b) can implement upstream of the hydrodemetallation or hydrotreatment catalyst(s) at least one guard bed containing adsorbents of type alumina, silica, silica-alumina, zeolite and/or activated carbon possibly containing metals from group VI B and/or VIII. It is also possible to use a series of guard beds with particles of different diameters, in particular a series of guard beds having decreasing diameters in the direction of the flow of the charge (also called “grading” according to Anglo-Saxon terminology). .
• molybdenum preferably from 3% to 20% by weight of molybdenum (expressed as molybdenum oxide MoOa) relative to the weight of the catalyst on a mineral support.
• the total content of metal oxides from groups VI B and VIII can be from 5% to 40% by weight, preferably from 5% to 30% by weight, relative to the weight of the catalyst, and the weight ratio expressed as metal oxide between metal (or metals) of group VI B on metal (or metals) of group VIII is generally between 20 and 1, and most often between 10 and 2.
• the support can for example be chosen from the group consisting of alumina, silica, silica-aluminas, magnesia, clays and mixtures of at least two of these minerals.
• this support may contain other doping compounds, in particular oxides chosen from the group consisting of boron oxide, zirconia, ceria, titanium oxide, phosphoric anhydride and a mixture of these oxides.
• An alumina support is most often used and very often an alumina support doped with phosphorus and possibly boron.
• P 2 Os When the phosphoric anhydride P 2 Os is present, its concentration is less than 10% by weight relative to the weight of the alumina and advantageously at least 0.001% by weight relative to the total weight of the alumina.
• boron trioxide B 2 Os When boron trioxide B 2 Os is present, its concentration is less than 10% by weight relative to the weight of the alumina and advantageously at least 0.001% relative to the total weight of the alumina.
• the alumina used can be a y (gamma) or q (eta) alumina.
• Said hydrodemetallation catalyst is for example in the form of extrudates
• Catalysts which can be used in step a) of hydrodemetallation in permutable reactors are for example indicated in patent documents EP 0113297, EP 0113284, US 5221656, US 5827421, US 7119045, US 5622616 and US 5089463.
• Said hydrodemetallation step a) makes it possible to obtain a hydrodemetallated effluent, that is to say with a reduced content of metals, including silicon, chlorine and a reduced content of olefins, in particular diolefins.
• metals including silicon, chlorine and a reduced content of olefins, in particular diolefins.
• olefins in particular diolefins.
• at least 50%, and more preferably at least 75% of the chlorine, silicon, metals and diolefins of the initial charge are respectively eliminated during step a).
• the content of Ni and V metals is generally less than 20 ppm by weight, and preferably less than 10 ppm by weight relative to the weight of effluent.
• the silicon content is generally less than 10 ppm by weight, and preferably less than 5 ppm by weight, preferably less than or equal to 2 ppm by weight, or even less than or equal to 1 ppm weight relative to the weight of the effluent.
• the chlorine content is generally less than 10 ppm by weight, and preferably less than 5 ppm by weight, preferably less than or equal to 2 ppm by weight, or even less than or equal to 1 ppm weight relative to the weight of effluent.
• the diolefin content is generally less than 5 mg/g, preferably less than 1 mg/g.
• the treatment process comprises a hydrotreatment step b) implemented in a reaction section comprising at least one fixed bed reactor, said section being supplied at least by said effluent from step a) and optionally a gas flow comprising hydrogen, in the presence of at least one hydrotreatment catalyst, at a temperature between 300 and 500°C, an absolute pressure between 5 MPa and 35 MPa and an hourly volume velocity between 0, 1 and 5.0 h -1 .
• Hydrotreatment step b) includes hydrotreatment reactions, but also hydroconversion reactions as defined above in the “definition” section.
• the conversion rate is moderate or even low, generally less than 45%, most often less than 35% at the end of the cycle, and less than 25% at the start of the cycle.
• the conversion rate generally varies during the cycle due to the increase in temperature to compensate for catalytic deactivation.
• the conversion rate is defined as being the mass fraction of organic compounds having a boiling point greater than 520°C in the feed at the entrance to the reaction section minus the mass fraction of organic compounds having a boiling point higher at 520°C at the outlet of the reaction section in the effluent, all divided by the mass fraction of organic compounds having a boiling point greater than 520°C at the entrance to the reaction section in the feed.
• step b) of hydrotreatment comprises a first step b1) of hydrodemetallation (HDM) carried out in one or more hydrodemetallation zones in fixed beds and a second subsequent step b2) of hydrodesulfurization (H DS ) carried out in one or more fixed bed hydrodesulfurization zones.
• first hydrodemetallation step b1) the effluent from step a) is brought into contact with a hydrodemetallation catalyst, under hydrodemetallation conditions, then during said second step b2) of hydrodesulfurization, the effluent from the first hydrodemetallation step b1) is brought into contact with a hydrodesulfurization catalyst, under hydrodesulfurization conditions.
• This process known under the name HYVAHL-FTM, is for example described in patent US 5417846.
• step b1) of hydrodemetallation hydrodemetallation reactions are carried out but in parallel also part of the other hydrotreatment reactions, and in particular hydrodesulfurization and hydrocracking.
• step b2) of hydrodesulfurization hydrodesulfurization reactions are carried out, but at the same time also part of the other hydrotreatment reactions and in particular hydrodemetallation and hydrocracking.
• the hydrotreatment step b) comprises a first hydrodemetallation step b1) carried out in one or more hydrodemetallation zones in fixed beds, a second subsequent transition step b2) carried out in one or more zones of transition into fixed beds, and a third subsequent step b3) of hydrodesulfurization carried out in one or more hydrodesulfurization zones in fixed beds.
• the effluent from step a) is brought into contact with a hydrodemetallation catalyst, under hydrodemetallation conditions, then during said second step b2) of transition, the effluent from the first step b1) of hydrodemetallation is brought into contact with a transition catalyst, under transition conditions, then during said third step b3) of hydrodesulfurization, the effluent from the second step b2) transition is brought into contact with a hydrodesulfurization catalyst, under hydrodesulfurization conditions.
• step b1) of hydrodemetallation according to the variants above in addition to step a) of hydrodemetallation in permutable guard reactors is justified when the hydrodemetallation carried out during step a) is not not sufficient to protect the catalysts of step b), in particular the hydrodesulfurization catalysts.
• Each fixed bed reactor comprises n catalytic beds, n being an integer greater than or equal to 1, each comprising at least one hydrotreatment catalyst.
• Hydrotreatment step b) is carried out under hydrotreatment conditions. It can advantageously be implemented at a temperature of between 300°C and 500°C, preferably between 350°C and 430°C and under an absolute pressure of between 5 MPa and 35 MPa, preferably between 11 MPa and 26 MPa, preferably between 14 MPa and 20 MPa. The temperature is usually adjusted based on the desired level of hydrotreatment and the targeted treatment duration.
• the space velocity of the charge also called hourly volume velocity (liquid hourly space velocity “LHSV” or hourly space velocity “HSV” according to Anglo-Saxon terminology), commonly called WH, and which is defined as being the volumetric flow rate of the charge divided by the total volume of the catalyst, can be included in a range going from 0.1 h -1 to 5 h -1 , preferably from 0.1 h -1 to 2 h -1 , and more preferably from 0.1 h -1 to 1 h' 1 .
• hourly volume velocity liquid hourly space velocity “LHSV” or hourly space velocity “HSV” according to Anglo-Saxon terminology
• the quantity of hydrogen mixed with the charge can be between 100 and 5000 normal cubic meters (Nm 3 ) per cubic meter (m 3 ) of liquid charge, preferably between 200 Nm 3 /m 3 and 2000 Nm 3 /m 3 , and more preferably between 300 Nm 3 /m 3 and 1500 Nm 3 /m 3 .
• Hydrotreatment step b) can be carried out industrially in one or more liquid downdraft reactors.
• the hydrotreatment catalysts used are preferably known catalysts. These may be granular catalysts comprising, on a support, at least one metal or metal compound having a hydro-dehydrogenating function. These catalysts can advantageously be catalysts comprising at least one metal from group VIII, generally chosen from the group consisting of nickel and cobalt, and/or at least one metal from group VI B, preferably molybdenum and/or tungsten. . For example, a catalyst comprising 0.5% to 10% by weight of nickel, preferably 1% to 5% by weight of nickel (expressed as nickel oxide NiO), and 1% to 30% by weight of nickel can be used.
• molybdenum preferably from 3% to 20% by weight of molybdenum (expressed as molybdenum oxide MoOa) relative to the weight of the catalyst, on a mineral support.
• This support can for example be chosen from the group consisting of alumina, silica, silica-aluminas, magnesia, clays and mixtures of at least two of these minerals.
• this support may contain other doping compounds, in particular oxides chosen from the group consisting of boron oxide, zirconia, ceria, titanium oxide, phosphoric anhydride and a mixture of these oxides.
• oxides chosen from the group consisting of boron oxide, zirconia, ceria, titanium oxide, phosphoric anhydride and a mixture of these oxides.
• the phosphoric anhydride P2O5 When the phosphoric anhydride P2O5 is present, its concentration is less than 10% by weight relative to the weight of the alumina and advantageously at least 0.001% by weight relative to the total weight of the alumina.
• boron trioxide B2O5 When boron trioxide B2O5 is present, its concentration is less than 10% by weight relative to the weight of the alumina and advantageously at least 0.001% relative to the total weight of the alumina.
• the alumina used can be a y (gamma) or q (eta) alumina.
• This catalyst is most often in the form of extrudates.
• the total content of metal oxides from groups VI B and VIII can be from 3% to 40% by weight and generally from 5% to 30% by weight relative to the weight of the catalyst, and the weight ratio expressed as metal oxide between metal (or metals) of group VIB on metal (or metals) of group VIII is generally between 20 and 1, and most often between 10 and 2.
• a hydrotreatment step including a hydrodemetallation step b1) (HDM) then a hydrodesulfurization step b2) (HDS)
• specific catalysts adapted to each step are preferably used.
• Catalysts which can be used in step b1) of hydrodemetallation are for example indicated in patent documents EP 0113297, EP 0113284, US 5221656, US 5827421, US 7119045, US 5622616 and US 5089463.
• Catalysts which can be used in step b3 ) hydrodesulfurization are for example indicated in patent documents EP 0113297, EP 0113284, US 6589908, US 4818743 or US 6332976.
• a mixed catalyst also called a transition catalyst, active in hydrodemetallation and hydrodesulfurization, both for the hydrodemetallation section b1) and for the hydrodesulfurization section b2) as described in patent document FR 2940143.
• a hydrotreatment step including a step b1) of hydrodemetallation (HDM) then a step b2) of transition, then a step b3) of hydrodesulfurization (HDS), specific catalysts adapted to each step.
• Catalysts which can be used in step b1) of hydrodemetallation are for example indicated in patent documents EP 0113297, EP 0113284, US 5221656, US 5827421, US 7119045, US 5622616 and US 5089463.
• Catalysts which can be used in step b2 ) transition, active in hydrodemetallation and hydrodesulfurization are for example described in patent document FR 2940143.
• Catalysts which can be used in step b3) of hydrodesulfurization are for example indicated in patent documents EP 0113297, EP 0113284, US 6589908, US 4818743 or US 6332976. It is also possible to use a transition catalyst as described in patent document FR 2940143 for sections b1), b2) and b3).
• Hydrotreatment step b) is carried out under conditions enabling a hydrotreated effluent to be obtained, that is to say with a reduced content of sulfur, nitrogen, asphaltenes and Conradson carbon.
• the sulfur content is generally less than 0.5% (5000 ppm) by weight, and preferably less than 0.48% (4800 ppm) by weight relative to the weight of effluent .
• the nitrogen content is generally less than 3500 ppm by weight, and preferably less than 3000 ppm by weight relative to the weight of effluent.
• the asphaltene content C? is generally less than 2% by weight, and preferably less than 1% by weight relative to the weight of effluent.
• the Conradson carbon content is generally less than 8% by weight, and preferably less than 6% by weight relative to the weight of the effluent.
• Said effluent from step b) of hydrotreatment contains the conversion products, in particular said effluent has a reduced content (compared to the feed) of hydrocarbons having an initial boiling temperature of at least 340°C, or at least 350°C, 375°C, 450°C, 460°C, 500°C, or even 600°C depending on the nature of the load.
• the method further comprises a separation step (c), which separates part, or all, of the effluent from step b) in a separation section leading to a gaseous effluent and to the least a liquid product.
• This separation step c) separates part or all of said effluent into several fractions including at least one liquid product which can be a light (naphtha, diesel, kerosene), intermediate (vacuum distillate) or heavy (vacuum residue) cut. .
• Separation step c) is implemented in a separation section which includes any separation means known to a person skilled in the art.
• Said separation section may comprise one or more flash drums arranged in series, and/or one or more steam and/or hydrogen stripping columns, and/or an atmospheric distillation column, and/or a column of vacuum distillation.
• this separation step c) is carried out by a sequence of at least two successive expansion tanks.
• this separation step c) is carried out by one or more steam and/or hydrogen stripping columns.
• this separation step c) is carried out by an atmospheric distillation column, and more preferably by an atmospheric distillation column and a vacuum column receiving the atmospheric residue.
• this separation step c) is carried out by one or more flash flasks, an atmospheric distillation column and a vacuum column receiving the atmospheric residue.
• the gaseous effluent includes in particular H2, H2S, NH3, and C1-C4 hydrocarbons.
• This gaseous effluent can be separated from the effluent obtained at the end of step b) using separation devices well known to those skilled in the art, in particular using one or more separator balloons. capable of operating at different pressures and temperatures, possibly associated with a steam or hydrogen stripping means and one or more distillation columns.
• the effluent obtained at the end of hydrotreatment step b) is advantageously separated in at least one separator flask into at least one gaseous effluent and at least one liquid product.
• These separators can for example be high pressure high temperature separators (HPHT) and/or high pressure low temperature separators (HPBT).
• this gaseous effluent is preferably treated in a hydrogen purification means so as to recover the hydrogen not consumed during the hydrodemetallation and hydrotreatment reactions.
• the hydrogen purification means may be an amine wash, a membrane, a PSA type system, or several of these means arranged in series.
• the purified hydrogen can then advantageously be recycled in the process according to the invention, after possible recompression.
• Hydrogen can be introduced at the inlet of hydrodemetallation step a) and/or at different locations during hydrotreatment step b). Hydrogen (hot because it leaves step c) can also be used to preheat the pyrolysis oil fraction when it is introduced separately from the heavy fraction.
• the recovered hydrogen gas can also be used in other refinery facilities.
• Separation step c) may also include atmospheric distillation and/or vacuum distillation.
• separation step c) further comprises at least one atmospheric distillation, in which the liquid effluent obtained after gas/liquid separation is fractionated by atmospheric distillation into at least one atmospheric distillate fraction and at least one atmospheric residue fraction.
• separation step c) of the process according to the invention may advantageously further comprise at least one vacuum distillation in which the liquid effluent obtained after gas/liquid separation and/or the atmospheric residue fraction obtained after atmospheric distillation is(are) fractionated by vacuum distillation into at least one vacuum distillate fraction and at least one vacuum residue fraction.
• separation step c) firstly comprises an atmospheric distillation, in which the liquid effluent obtained after gas/liquid separation is fractionated by atmospheric distillation into at least one atmospheric distillate fraction and at least one residue fraction.
• atmospheric then vacuum distillation in which the atmospheric residue fraction obtained after atmospheric distillation is fractionated by vacuum distillation into at least one vacuum distillate fraction and at least one vacuum residue fraction.
• the vacuum distillate fraction typically contains vacuum gas oil type fractions.
• the separation section can also include means for washing at least one section separated by contact with an aqueous solution.
• This washing makes it possible in particular to eliminate the ammonium chloride salts essentially coming from the pyrolysis oil fraction.
• These salts are formed by reaction between chloride ions, released by the hydrogenation of chlorinated compounds in HCl form during steps a) and b) then dissolved in water, and ammonium ions, generated by the hydrogenation of nitrogen compounds in the form of NH3 during steps a) and b) and/or provided by injection of a amine then dissolved in water. Washing thus makes it possible to limit the risks of blockage, in particular in the transfer lines and/or in the sections of the process of the invention, due to the precipitation of ammonium chloride salts. It also makes it possible to eliminate the hydrochloric acid formed by the reaction of hydrogen ions and chloride ions and therefore to limit corrosion in downstream equipment.
• the separation step (c) comprises: c1) a first separation step carried out at a temperature higher than the precipitation temperature of ammonium halides to obtain at least a first gaseous fraction and a liquid effluent, c2) a second separation step, supplied with first gaseous fraction and at least part of the liquid effluent from step c1) and an aqueous solution, said step being carried out at a temperature lower than the temperature of precipitation of ammonium halides to obtain at least a second gaseous fraction, an aqueous effluent and a liquid product.
• the objective of this separation by the combination of hot separation step c1) followed by cold separation/washing step c2) is to eliminate chlorine in the form of ammonium chloride salts.
• precipitation temperature of ammonium halides is meant the temperature (under given conditions, such as concentration and pressure) at which gaseous ammonia and hydrogen halides precipitate, either by reacting to form solid crystals of ammonium halides, or by dissolving in water.
• the precipitation temperature depends on the halide concentrations and pressure according to thermodynamic principles.
• Halide precipitation temperature of ammonium are generally between 150 and 300 ° C under the conditions of use of the present process.
• the separation equipment or flasks may include at the bottom a zone allowing the separate decantation of a hydrocarbon fraction and an aqueous fraction comprising chloride salts, or even include a gas washing column by bringing it into contact with water or a basic solution.
• One or more subsequent treatment steps (d) of the liquid product(s) resulting from separation step c) can be carried out.
• Such a step d) may comprise at least one step chosen from the list consisting of hydrotreatment, steam cracking, catalytic cracking in a fluidized bed, hydrocracking, deasphalting, extraction of lubricating oils. These examples of further processing are not exhaustive.
• bases of the naphtha, kerosene and diesel type can be upgraded in a refinery for the production of fuels for automobiles and aviation, such as for example premium fuels, Jet fuels and gas oils, either directly or after possible hydrotreatment.
• part of the gases comprising hydrocarbons with 2 to 4 carbon atoms, naphtha, kerosene and diesel type bases can be upgraded in a steam cracking unit in order to be able to obtain in particular light olefins which can be used as monomers in the manufacture of polymers.
• naphtha, kerosene and diesel type bases can be upgraded in a fluidized bed catalytic cracking unit (FCC for Fluid Catalytic Cracking according to Anglo-Saxon terminology) or even in a hydrocracking unit.
• FCC Fluid Catalytic Cracking according to Anglo-Saxon terminology
• the vacuum distillate can be upgraded in a hydrocracking unit.
• the atmospheric residue and/or vacuum residue (unconverted) can be sent to a catalytic cracking (FCC) process, a hydrocracking process or even desalphating.
• FCC catalytic cracking
• the atmospheric residue fraction and/or the vacuum residue fraction may be used as low sulfur marine fuels, in particular marine distillates and/or marine residual fuels. , generally called bunker fuel.
• low sulfur marine fuels in particular marine distillates and/or marine residual fuels.
• bunker fuel generally called bunker fuel.
• Fluxants generally chosen from light cutting oils from catalytic cracking (LCO for Light Cycle Oil according to the FCC term), heavy cutting oils from catalytic cracking (HCO for Heavy Cycle Oil according to the term in English from FCC), the residue of a catalytic cracking, a kerosene, a gas oil, a vacuum distillate and/or a decanted oil are generally added to lower the viscosity of a bunker fuel oil.
• the presence of a pyrolysis oil as a co-charge in the treatment of a heavy charge of fossil origin makes it possible in particular to directly obtain a fuel oil respecting the specifications in terms of sulfur, sediments and viscosity without the need to add a flux.
• the sulfur specifications for a fuel oil are a sulfur content less than 0.5% w/ppm (ISO8217).
• RMG 380 is a most common bunker fuel oil grade according to ISO8217 and the viscosity specification for RMG 380 grade bunker fuel oil is viscosity less than 380 cST at 50°C.
• Another very restrictive recommendation is the sediment content after aging according to ISO 10307-2 (also known as IP390) which must be less than or equal to 0.1%.
• FIG. 1 schematically illustrates an embodiment of the method according to the invention.
• FIG. 1 describes a simplified diagram for implementing the chain of reactors of the invention without limiting its scope. For the sake of simplicity, only the reactors are shown, but it is understood that all the equipment necessary for operation is present (balloons, pumps, exchangers, ovens, columns, etc.). Only the main flows containing hydrocarbons are represented, but it is understood that gas flows rich in hydrogen (make-up or recycle) can be injected at the inlet of each catalytic bed or between two beds.
• the feed comprising a heavy fraction of hydrocarbons 1 and a minor fraction of pyrolysis oil of plastics and/or tires and/or CSR 2, optionally pretreated (not shown), enters a fixed bed reaction unit comprising guard reactors permutable elements consisting of Ra and Rb reactors, to carry out a hydrodemetallation step a).
• the pyrolysis oil fraction can be mixed beforehand with the heavy hydrocarbon fraction of the feed before entering the first hydrodemetallation reactor.
• Another variant is the separate injection of the pyrolysis oil fraction and the heavy hydrocarbon fraction into the first hydrodemetallization reactor (not shown).
• the effluent 3 from step a) of hydrodemetallation in permutable guard reactors is sent to a fixed bed reaction section consisting of reactors R1, R2 and R3 to carry out step b) of hydrotreatment.
• the fixed bed hydrotreatment reactors can for example be charged respectively with hydrodemetallation, transition and hydrodesulfurization catalysts.
• the effluent 4 from the fixed bed hydrotreatment step is sent to a separation section 5 to proceed to the separation step and separate a gaseous effluent 6 and at least one liquid product 7.
• Each Ra and Rb reactor can be taken offline in order to change the catalyst without stopping the rest of the unit.
• This change of catalyst is generally allowed by a conditioning section not shown.
• sequence 1 the charge passes through the reactors Ra and Rb, then R1, R2 and R3.
• the Ra reactor catalyst is no longer sufficiently active (metal poisoning and/or coking) and/or the clogging reaches too high a pressure drop, the permutation for catalyst change occurs.
• reactor Ra is taken offline, the charge enters directly into reactor Rb, then passes through R1, R2 and R3. During this sequence 2, the spent catalyst from the Ra reactor is discharged and the Ra reactor is recharged with fresh catalyst.
• sequence 3 the reactor Ra containing the fresh catalyst is put online in such a way that the charge first passes through the reactor Rb containing a partially spent catalyst, then the reactor Ra, then R1, R2 and R3.
• the catalyst of the Rb reactor is no longer sufficiently active and/or the clogging reaches too high a pressure drop, another permutation for catalyst change occurs.
• the spent catalyst from the Rb reactor is discharged and the Rb reactor is recharged with fresh catalyst; the charge enters directly into the reactor Ra, then passes through R1, R2 and R3.
• sequence 5 the reactor Rb containing the fresh catalyst is put online in such a way that the charge first passes through the reactor Ra containing a partially spent catalyst, then the reactor Rb, then R1, R2 and R3.
• Sequence 5 being identical to sequence 1, this demonstrates the cyclical nature of the proposed operation.
• the following table gives examples of sequences that can be carried out according to Figure 1:
• Analysis methods used The analysis methods and/or standards used to determine the characteristics of the different flows, in particular the load to be treated and the effluents produced, are known to those skilled in the art. They are specifically listed in Table 2 below for information purposes. Other methods deemed equivalent may also be used, in particular IP, EN or ISO equivalent methods.
• Example 1 is a comparative example illustrating the performance of the treatment process for a reference load (vacuum residue) without plastic pyrolysis oil.
• Example 2 illustrates the performance of a treatment process with a load comprising a fraction of plastic pyrolysis oil and a fraction of the reference load (vacuum residue) used in Example 1.
• the mixture has was implemented during a pre-step of homogenization of the medium (optional step).
• the heavy fraction (I) of the feed is a vacuum residue coming directly from the distillation of a petroleum crude (called straight-run according to Anglo-Saxon terminology (RSV-SR)).
• the plastic pyrolysis oil fraction (II) of the feed is a pyrolysis oil derived from a mixture of plastics and containing a significant level of impurities.
• the treatment process involves the use of two swappable reactors Ra and Rb in the first hydrodemetallation stage (H DM) upstream of a hydrotreatment section composed of 4 fixed bed reactors (R1, R2, R3 and R4) .
• the operating conditions are similar for the two examples and they are summarized in Table 4 below.
• plastic pyrolysis oil makes it possible to eliminate the need to add a fluxing cut to achieve the sulfur and viscosity specifications imposed by the ISO 8217 standard for an RMG 380 type bunker fuel oil.
• the formulation of the bunker fuel oil does not require the use of the entire cut [180-350°C], unlike this which we observe in example 1. This “excess” cut can therefore be sent to the steam cracker with the PI-180°C cut or serve as a basis for the formulation of other fuels.

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