EP3415588A1 - Integriertes hydrocracking-verfahren in zwei stufen, und hydrotreating-verfahren - Google Patents

Integriertes hydrocracking-verfahren in zwei stufen, und hydrotreating-verfahren Download PDF

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Publication number
EP3415588A1
EP3415588A1 EP18305724.9A EP18305724A EP3415588A1 EP 3415588 A1 EP3415588 A1 EP 3415588A1 EP 18305724 A EP18305724 A EP 18305724A EP 3415588 A1 EP3415588 A1 EP 3415588A1
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Prior art keywords
hydrogen
hydrocracking
effluent
hydrocarbon
liquid
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English (en)
French (fr)
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EP3415588B1 (de
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Jan Verstraete
Elodie Tellier
Thomas PLENNEVAUX
Emmanuelle Guillon
Anne-Claire PIERRON
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IFP Energies Nouvelles IFPEN
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IFP Energies Nouvelles IFPEN
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    • 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
    • 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
    • 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
    • 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
    • C10G47/00—Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen- generating compounds, to obtain lower boiling fractions
    • 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
    • C10G47/00—Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen- generating compounds, to obtain lower boiling fractions
    • C10G47/36—Controlling or regulating
    • 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
    • C10G49/00—Treatment of hydrocarbon oils, in the presence of hydrogen or hydrogen-generating compounds, not provided for in a single one of groups C10G45/02, C10G45/32, C10G45/44, C10G45/58 or C10G47/00
    • 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
    • C10G49/00—Treatment of hydrocarbon oils, in the presence of hydrogen or hydrogen-generating compounds, not provided for in a single one of groups C10G45/02, C10G45/32, C10G45/44, C10G45/58 or C10G47/00
    • C10G49/26—Controlling or regulating
    • 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
    • C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
    • C10G2300/10—Feedstock materials
    • C10G2300/1011—Biomass
    • 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
    • C10G2300/1037—Hydrocarbon fractions
    • 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
    • C10G2300/1037—Hydrocarbon fractions
    • C10G2300/1048—Middle distillates
    • C10G2300/1059—Gasoil having a boiling range of about 330 - 427 °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
    • C10G2300/107—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
    • C10G2300/1074—Vacuum distillates
    • 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
    • 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
    • C10G2300/4006—Temperature
    • 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
    • C10G2300/4012—Pressure
    • 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
    • C10G2300/4081—Recycling aspects
    • 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
    • C10G47/00—Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen- generating compounds, to obtain lower boiling fractions
    • C10G47/02—Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen- generating compounds, to obtain lower boiling fractions characterised by the catalyst used

Definitions

  • Hydrocracking of heavy oil cuts is a key refining process that makes it possible to produce lighter fractions, such as gasolines, light fuel oils and fuels, which the refiner seeks in order to adapt his production to the request.
  • Certain hydrocracking processes also make it possible to obtain a highly purified residue that can constitute excellent bases for oils or a charge which can be easily upgraded in a catalytic cracking unit, for example.
  • One of the effluents particularly targeted by the hydrocracking process is the middle distillate (fraction which contains the gasoil fraction and the kerosene fraction).
  • DSV hydrocracking vacuum distillates or DSV allows to produce light cuts (Gasoil, Kerosene, naphtha, ...) more valuable than the DSV itself.
  • This catalytic process does not make it possible to completely transform the DSV into light cuts.
  • UCO Non-converted DSV fraction
  • UCO UnConverted Oil according to the English terminology.
  • this unconverted fraction can be recycled to the inlet of the hydrotreatment reactor or to the inlet of the hydrocracking reactor. Recycling the unconverted fraction at the inlet of the hydrotreatment reactor or at the inlet of the hydrocracking reactor makes it possible at the same time to increase the conversion, but also makes it possible to increase the selectivity in gas oil and kerosene.
  • Another way to increase the conversion by maintaining the selectivity is to add a conversion or hydrocracking reactor on the recycle loop of the unconverted fraction to the high pressure separation section.
  • This reactor and the associated recycle constitute a second hydrocracking step. Since this reactor is located downstream of the fractionation section, it operates with little sulfur (H 2 S) and little nitrogen, which makes it possible to optionally use catalysts that are less sensitive to the presence of sulfur by increasing the selectivity of the reactor. process.
  • the two-step hydrocracking comprises a first step whose objective, as in the "one-step” process, is to perform the hydrorefining of the feedstock but also to achieve a conversion of the latter from the order to the feedstock. from 30 to 70%.
  • the effluent from the first stage is then subjected to fractionation (distillation), the purpose of which is to separate the conversion products from the unconverted fraction.
  • fractionation distillation
  • the second step of a 2-step hydrocracking process only the fraction of the unconverted feedstock in the first step is processed. This separation allows a two-stage hydrocracking process to be more selective in diesel than a one-step process with equivalent overall conversion rate.
  • the intermediate separation of the conversion products avoids their "over-cracking" in naphtha and gas in the second step on the hydrocracking catalyst.
  • the unconverted fraction of the feedstock treated in the second stage generally contains very low levels of NH 3 as well as organic nitrogen compounds, generally less than 20 ppm by weight or less than 10 ppm by weight.
  • the hydrodesulphurization process of gas oils makes it possible to reduce the amount of sulfur contained in a diesel fuel cut while minimizing the conversion of the feedstock into lighter products (gas, naphtha).
  • the charge of hydrodesulphurization can consist of straight run gas oil according to the English terminology or diesel fuel resulting from the atmospheric fractionation of a crude oil, of Light Vacuum Gasoil Oil according to the English terminology or light vacuum distillate, of LCO. or distillate from a conversion process (FCC, coker ...), a diesel fuel charge resulting from the conversion of biomass (esterification for example), alone or in mixture, for example.
  • the hydrogen partial pressure required for this process is lower than the hydrogen partial pressure in the hydrocracker. It is common for these two processes to be present in the same refinery without being integrated. However, they are based on very similar process diagrams, consisting of a charging furnace, fixed bed reactors, hydrogen recycle compressors, and more or less complex high pressure separation sections.
  • the invention consists in integrating a two-stage hydrocracking process with a gas oil hydrodesulphurization process by using at least a portion of the reactor of the second hydrocracking stage to desulphurize the diesel fuel feedstock in mixture with the unconverted fraction or UCO. .
  • the present invention relates to a two-stage hydrocracking process of a vacuum distillate type hydrocarbon feedstock in which all of the effluent from the second hydrocracking stage e) is co-treated in a hydrotreatment stage. f) located downstream of said second hydrocracking step e), in admixture with a hydrocarbon liquid hydrocarbon feedstock, distinct from said effluent resulting from the second hydrocracking step e).
  • Another advantage of the present invention is to provide a process which allows, by the implementation of a co-treatment of the effluent resulting from the hydrocracking step e) mixed with a hydrocarbon liquid hydrocarbon feedstock in a step f) hydrotreating, downstream of the hydrocracking step e), in addition to desulfurizing the hydrocarbon-type liquid hydrocarbon feedstock, to convert the unconverted portion of the effluent from the hydrocracking step e), which makes it possible to reduce the amount of catalyst used in said step i) of hydrocracking, at iso-conversion by pass of the step consisting of the combination of the second hydrocracking step e) and of step f ) hydrotreatment,
  • Another advantage of the present invention is to provide a process which, by using said co-treatment, makes it possible in addition to desulphurize the hydrocarbon liquid feed of the diesel type, to minimize the formation of polyaromatic heavy products (HPNA). Indeed, the HPNA is gradually formed during their recycling in the second hydrocracking step.
  • the implementation of the hydrotreatment step f) downstream of the hydrocracking step e) makes it possible to limit the growth of the HPNAs by hydrogenating the precursors of said HPNAs, that is to say the low-weight HPNAs. molecular).
  • Another advantage of the present invention is to provide a process which by the integration of two processes allows the reduction of operating costs and the reduction of the catalyst consumption in the second hydrocracking step.
  • the process comprises a step a) of hydrocracking said charges operating, in the presence of hydrogen and at least one hydrocracking catalyst, at a temperature of between 250 and 480 ° C., under a pressure of between 2 and 25 MPa, at a space velocity of between 0.1 and 6 h -1, and with a quantity of hydrogen introduced such that the ratio by volume of hydrogen liter / liter of hydrocarbon is between 100 and 2000 L. / L.
  • Operating conditions such as temperature, pressure, hydrogen recycling rate, hourly space velocity, may be very variable depending on the nature of the load, the quality of desired products and facilities available to the refiner.
  • the hydrocracking step a) operates at a temperature of between 320 and 450 ° C., very preferably between 330 and 435 ° C., under a pressure of between 3 and 20 MPa, and very preferably between 6 and 20 MPa, at a space velocity of between 0.2 and 4 h -1, very preferably between 0.3 and 5 h -1 and with a quantity of hydrogen introduced such as the volume ratio.
  • liter of hydrogen / liter of hydrocarbon is between 200 and 2000 L / L.
  • step a) of the process according to the invention generally make it possible to achieve pass conversions, products having boiling points below 340 ° C., and better still below 370 ° C., greater than 15% by weight and even more preferably between 20 and 95% by weight.
  • the hydrocarbon feeds treated in the process according to the invention and sent to step a) are chosen from hydrocarbon feeds containing at least 20% by volume and preferably at least 80% by volume of compounds boiling over above 340 ° C and preferably between 370 and 580 ° C (that is, corresponding to compounds containing at least 15 to 20 carbon atoms).
  • Said hydrocarbon feedstocks may advantageously be chosen from VGO (Vacuum gas oil) according to the English terminology or vacuum distillates (DSV), such as, for example, gas oil obtained from the direct distillation of the crude or from conversion units such as FCC, coker or visbreaking as well as feedstocks from aromatic extraction units of lubricating oil bases or from solvent dewaxing of lubricating oil bases, or distillates from desulphurization or hydroconversion of RAT (atmospheric residues) and / or RSV (vacuum residues), or the charge may advantageously be a deasphalted oil, or charges from the biomass or any mixture of the aforementioned fillers.
  • VGO Vauum gas oil
  • DSV vacuum distillates
  • the charge may advantageously be a deasphalted oil, or charges from the biomass or any mixture of the aforementioned fillers.
  • said fillers have an initial boiling point greater than 340 ° C, and preferably greater than 370 ° C.
  • Said hydrocarbon feeds may contain heteroatoms such as sulfur and nitrogen.
  • the nitrogen content is usually between 1 and 8000 ppm by weight, more generally between 200 and 5000 ppm by weight, and the sulfur content between 0.01 and 6% by weight, more generally between 0.2 and 5%, and still more more preferred between 0.5 and 4% by weight.
  • Said feedstock treated in the process according to the invention and sent in step a) may optionally contain metals.
  • the cumulative nickel and vanadium content of the feeds treated in the processes according to the invention is preferably less than 1 ppm by weight.
  • the asphaltene content is generally less than 3000 ppm by weight, preferably less than 1000 ppm by weight, more preferably less than 200 ppm by weight.
  • the feedstock contains resins and / or asphaltenes-type compounds
  • the hydrocracking step a) operates in the presence of at least one hydrocracking catalyst.
  • the hydrocracking catalyst is chosen from conventional hydrocracking catalysts known to those skilled in the art.
  • the hydrocracking catalysts used in the hydrocracking processes are all of the bifunctional type associating an acid function with a hydrogenating function.
  • the acid function is provided by supports with large surface areas (generally 150 to 800 m 2 .g -1) having a surface acidity, such as halogenated aluminas (chlorinated or fluorinated in particular), combinations of boron oxides and aluminum, amorphous silica-aluminas and zeolites.
  • the hydrogenating function is provided either by one or more metals of group VIII of the periodic table of elements, or by a combination of at least one metal of group VIB of the periodic table and at least one metal of group VIII.
  • the hydrocracking catalyst or catalysts comprise a hydrogenating function comprising at least one group VIII metal chosen from iron, cobalt, nickel, ruthenium, rhodium, palladium and platinum and preferably cobalt and nickel and / or at least one Group VIB metal selected from chromium, molybdenum and tungsten, alone or in admixture and preferably from molybdenum and tungsten.
  • group VIII metal chosen from iron, cobalt, nickel, ruthenium, rhodium, palladium and platinum and preferably cobalt and nickel and / or at least one Group VIB metal selected from chromium, molybdenum and tungsten, alone or in admixture and preferably from molybdenum and tungsten.
  • the group VIII metal content in the hydrocracking catalyst or catalysts is advantageously between 0.5 and 15% by weight and preferably between 2 and 10% by weight, the percentages being expressed as a percentage by weight of oxides.
  • the group VIB metal content in the hydrocracking catalyst (s) is advantageously between 5 and 25% by weight and preferably between 15 and 22% by weight, the percentages being expressed as a percentage by weight of oxides.
  • the catalyst or catalysts may also optionally have at least one promoter element deposited on the catalyst and selected from the group consisting of phosphorus, boron and silicon, optionally at least one group VIIA element (chlorine, fluorine preferred), and optionally at least one minus one element of group VIIB (preferred manganese), optionally at least one element of group VB (preferred niobium).
  • the hydrocracking catalyst or catalysts comprise an acidic functional group chosen from alumina, silica-alumina and zeolites, preferably chosen from zeolites Y and preferably chosen from silica-alumina and zeolites.
  • a preferred catalyst comprises and preferably consists of at least one Group VI metal and / or at least one non-noble Group VIII metal, and a Y zeolite and an alumina binder.
  • An even more preferred catalyst comprises and is preferably made of nickel, molybdenum, zeolite Y and alumina.
  • Another preferred catalyst comprises and is preferably made of nickel, tungsten and alumina or silica alumina.
  • step a) of the process according to the invention the conversion, during the first step, to products having boiling points below 340 ° C., and better still below 370 ° C., is greater than 20% and preferably greater than 30% and even more preferably between 30 and 80% and preferably between 40 and 60%.
  • hydrocarbon feedstocks treated in the process according to the invention and sent to step a) may optionally be sent to a hydrotreating step before being sent to the hydrocracking step a) of said process.
  • said feeds are advantageously desulphurized and dis-nitrogenated.
  • said hydrotreating step is advantageously carried out under the conventional hydrorefining conditions and in particular in the presence of hydrogen and of a hydrotreatment catalyst and at a temperature of between 200 and 400.degree. pressure of between 2 and 16 MPa, at a space velocity of between 0.2 and 5 h -1, and with a quantity of hydrogen introduced such that the volume ratio by volume of hydrogen per liter of hydrocarbon is between 100 and 2000. L / L.
  • Conventional hydrotreatment catalysts may advantageously be used, preferably containing at least one amorphous support and at least one selected hydro-dehydrogenating element among at least one element of the non-noble groups VIB and VIII, and most often at least one element of the group VIB and at least one element of the non-noble group VIII.
  • the amorphous support is alumina or silica alumina.
  • Preferred catalysts are chosen from NiMo catalysts on alumina and NiMo or NiW on silica alumina.
  • the effluent from the hydrotreating step and entering the hydrocracking step a) comprises a nitrogen content preferably less than 300 ppm by weight and preferably less than 50 ppm by weight.
  • the hydrotreatment step and the hydrocracking step a) may advantageously be carried out in the same reactor or in different reactors.
  • the reactor comprises a plurality of catalytic beds, the first catalytic beds comprising the hydrotreatment catalyst (s) and the following catalytic beds comprising the hydrocracking catalyst (s).
  • the process comprises a step b) of gas / liquid separation of the effluent from step a) to produce a liquid effluent and a gaseous effluent comprising at least hydrogen.
  • the gas / liquid separation step b) is carried out in a high-pressure high-temperature separator operating at a temperature of between 50 and 450 ° C., preferably between 100 and 400 ° C., still more preferably between 200 and 300 ° C, and a pressure corresponding to the outlet pressure of a) less losses.
  • the process comprises a step c) of sending the gaseous effluent comprising at least hydrogen in a compression step before its recycling in at least the hydrocracking step a).
  • This step is necessary to allow the gas recycle upstream that is to say in step a) hydrocracking, so at higher pressure.
  • the gaseous effluent comprising at least hydrogen may advantageously be mixed with makeup hydrogen before or after its introduction in the compression step c), preferably via a supplemental hydrogen compressor or make up according to the English terminology.
  • a part of the gaseous effluent comprising at least compressed hydrogen can also advantageously be sent in the hydrocracking and / or hydrotreating steps e).
  • the process comprises a step d) of fractionation of the liquid effluent resulting from step a) into at least one effluent comprising the converted hydrocarbon products having boiling points below 340 ° C, preferably below 370 ° C and preferably below 380 ° C and an unconverted liquid fraction having a boiling point greater than 340 ° C, preferably greater than 370 ° C C and preferably above 380 ° C also called UCO or "unconverted oil" according to English terminology.
  • said fractionation step d) comprises a first separation step comprising a separation means such as, for example, a separator flask or a steam stripper preferably operating at a pressure of between 0.5 and 2 MPa, which aims to achieve a hydrogen sulfide (H 2 S) separation of at least one hydrocarbon effluent produced during the hydrocracking step a).
  • the hydrocarbon effluent from this first separation can advantageously undergo atmospheric distillation, and in some cases the combination of atmospheric distillation and vacuum distillation.
  • the distillation is intended to achieve a separation between the converted hydrocarbon products, that is to say generally having boiling points of less than 340 ° C., preferably less than 370 ° C. and preferably less than 38 ° C., and an unconverted liquid fraction (residue) (UCO).
  • a separation means such as, for example, a separator flask or a steam stripper preferably operating at a pressure of between 0.5 and 2 MPa, which aims to achieve a hydrogen
  • the fractionation step consists only of an atmospheric distillation column.
  • the converted hydrocarbon products having boiling points below 340.degree. C., preferably below 370.degree. C. and preferably below 380.degree. C., are advantageously distilled at atmospheric pressure in order to obtain several converted fractions having a boiling point. at most 340 ° C, and preferably a light gas fraction C1-C4, at least a gasoline fraction and at least a middle distillate fraction kerosene and gas oil.
  • the liquid fraction, unconverted residue (UCO) containing products whose boiling point is greater than 340 ° C., preferably greater than 370 ° C. and preferably greater than 380 ° C. and resulting from the distillation, is at least partly and preferably wholly introduced into the second hydrocracking step e) of the process according to the invention.
  • a purge can advantageously be carried out on the liquid fraction residue in order to avoid the accumulation of polyaromatic heavy products (HPNA) present in the recycling loop of heavy cuts.
  • HPNA polyaromatic heavy products
  • the HPNA is gradually formed during their recycling in the second hydrocracking step and the recycling of these heavy aromatic components in the loop of the second hydrocracking step e) has the consequence of increasing their molecular weight.
  • the presence of the HPNA in said recycling loop eventually leads to a significant pressure drop.
  • a purge is therefore necessary in order to limit the accumulation of these HPNA products.
  • the process comprises a step e) of hydrocracking said unconverted liquid fraction from step d), optionally purged, operating in the presence of hydrogen and a hydrocracking catalyst, at a temperature of between 250 and 480 ° C., at a pressure of between 2 and 25 MPa, at a space velocity of between 0.1 and 6 h -1 and with a quantity of hydrogen introduced such that the volume ratio liter of hydrogen / liter of hydrocarbon is between 100 and 2000 L / L.
  • the hydrocracking step e) operates at a temperature of between 320 and 450 ° C., very preferably between 330 and 435 ° C., under a pressure of between 3 and 20 MPa, and very preferably between 9 and 20 MPa, at a space velocity of between 0.2 and 3 h -1, and with a quantity of hydrogen introduced such that the volume ratio by liter of hydrogen / liter of hydrocarbon is between 100 and 2000 L / L.
  • stage e) of the process according to the invention generally make it possible to achieve pass conversions in products having boiling points below 340 ° C., preferably below 370 ° C. and preferred lower than 380 ° C, greater than 15% by weight and even more preferably between 20 and 80% by weight. Nevertheless, the pass conversion in step e) is kept low in order to maximize the selectivity of the process to product having boiling points between 150 and 370 ° C (middle distillates). Pass conversion is limited by the use of a high recycle rate on the second hydrocracking step loop. This rate is defined as the ratio between the feed rate of step e) and the feed rate of step a), preferably this ratio is between 0.2 and 4, preferably between 0, 5 and 2.
  • the hydrocracking step e) operates in the presence of at least one hydrocracking catalyst.
  • the second-stage hydrocracking catalyst is chosen from conventional hydrocracking catalysts known to those skilled in the art.
  • the hydrocracking catalyst used in said step e) may be the same or different from that used in step a) and preferably different.
  • the hydrocracking catalysts used in the hydrocracking processes are all of the bifunctional type associating an acid function with a hydrogenating function.
  • the acid function is provided by supports with large surface areas (generally 150 to 800 m 2 .g -1) having a surface acidity, such as halogenated aluminas (chlorinated or fluorinated in particular), combinations of boron oxides and aluminum, amorphous silica-aluminas and zeolites.
  • the hydrogenating function is provided either by one or more metals of group VIII of the periodic table of elements, or by a combination of at least one metal of group VIB of the periodic table and at least one metal of group VIII.
  • the hydrocracking catalyst or catalysts used in step e) comprise a hydrogenating function comprising at least one metal of group VIII chosen from iron, cobalt, nickel, ruthenium, rhodium, palladium and platinum and preferably cobalt and nickel and / or at least one Group VIB metal selected from chromium, molybdenum and tungsten, alone or as a mixture and preferably from molybdenum and tungsten.
  • group VIII chosen from iron, cobalt, nickel, ruthenium, rhodium, palladium and platinum and preferably cobalt and nickel and / or at least one Group VIB metal selected from chromium, molybdenum and tungsten, alone or as a mixture and preferably from molybdenum and tungsten.
  • the group VIII metal content in the hydrocracking catalyst or catalysts is advantageously between 0.5 and 15% by weight and preferably between 2 and 10% by weight, the percentages being expressed as a percentage by weight of oxides.
  • the group VIB metal content in the hydrocracking catalyst (s) is advantageously between 5 and 25% by weight and preferably between 15 and 22% by weight, the percentages being expressed as a percentage by weight of oxides.
  • the catalyst or catalysts used in step e) may also optionally comprise at least one promoter element deposited on the catalyst and chosen from the group formed by phosphorus, boron and silicon, optionally at least one element of group VIIA (chlorine , preferably fluorine), and optionally at least one member of the group VIIB (preferred manganese), optionally at least one member of the VB group (preferred niobium).
  • the hydrocracking catalyst or catalysts used in step e) comprise an acid functional group chosen from alumina, silica-alumina and zeolites, preferably chosen from zeolites Y and preferably chosen from silica-alumina and zeolites.
  • a preferred catalyst used in step e) comprises and preferably consists of at least one Group VI metal and / or at least one non-noble Group VIII metal, a Y zeolite and alumina.
  • An even more preferred catalyst comprises and is preferably made of nickel, molybdenum, zeolite Y and alumina.
  • Another preferred catalyst comprises and is preferably made of nickel, tungsten and alumina or silica alumina.
  • the process comprises a step f) of hydrotreating the effluent from step e) mixed with a hydrocarbonaceous liquid filler comprising at least 95% by weight of boiling compounds at a boiling temperature of between 150 and 400 ° C, preferably between 150 and 380 ° C and preferably between 200 and 380 ° C.
  • Said hydrocarbon liquid charge may advantageously be a charge originating from a unit external to said process according to the invention or a flow internal to said process according to the invention, said internal flow being different from said effluent resulting from the second hydrocracking step e).
  • said hydrocarbon liquid feedstock is a feedstock from a unit external to said process according to the invention.
  • said hydrocarbon liquid feedstock treated in step f) mixed with the effluent from step e) is advantageously chosen from hydrocarbon liquid feedstocks resulting from the direct distillation of a crude oil (or straight run according to Anglo-Saxon terminology) and preferably chosen from the straight run gas oil, the Light Vacuum Gasoil Oil (LVGO) according to the English terminology or light vacuum distillate, and the hydrocarbon liquid charges from a coking unit (coking).
  • LVGO Light Vacuum Gasoil Oil
  • Said hydrocarbon liquid feed may also advantageously be a hydrocarbon liquid feedstock derived from an H-oil boiling bed conversion unit.
  • the proportion of said distinct hydrocarbon liquid feed co-treated with the effluent from step e) in step f) represents between 20% and 80% by weight of the total mass of the total liquid mixture at the inlet of the f) hydrotreating step, preferably between 30% and 70% by weight and even more preferably between 40% and 60% by weight.
  • HPNA polyaromatic heavy products
  • Minimizing the formation of the HPNAs makes it possible to minimize the required purge on the liquid fraction, unconverted residue (UCO) resulting from step d) and therefore to increase the overall conversion of the process.
  • the purge rate corresponding to the ratio between the mass flow rate of the purge flow and the mass flow rate of the hydrocarbon feedstock entering the process according to the invention is advantageously between 0 and 2%.
  • said step f) operates in the presence of hydrogen and at least one hydrotreatment catalyst, at a temperature of between 200 and 390 ° C., at a pressure of between 2 and 16 MPa, at a temperature of a space velocity of between 0.2 and 5 h -1 and a quantity of hydrogen introduced such that the volume ratio by liter of hydrogen / liter of hydrocarbon is between 100 and 2000 L / L.
  • Conventional hydrotreatment catalysts may advantageously be used in said step f), which preferably contain at least one amorphous support and at least one hydro-dehydrogenating element chosen from at least one non-noble group VIB and VIII, and preferably at least one group VIB element and at least one non-noble group VIII element.
  • the amorphous support is alumina or silica alumina.
  • Preferred catalysts are chosen from NiMo or CoMo catalysts on alumina and NiMo or NiW on silica alumina.
  • the hydrotreatment step f) also allows the conversion of the unconverted portion of the effluent from the hydrocracking step e), which makes it possible to reduce the amount of catalyst used in the step e) hydrocracking iso-conversion step of the step consisting of the combination of the hydrocracking step e) and hydrotreating step f) Furthermore, the presence of the hydrotreatment step f ) increases the amount of hydrogen in the recycle of the unconverted liquid fraction having a boiling point higher than 340 ° C (UCO) to the hydrocracking step e), which facilitates their conversion in said step e) and thus further decreases the amount of catalyst required in said step (at iso-life).
  • UAO 340 ° C
  • the hydrocracking step e) and the hydrotreatment step f) can advantageously be carried out in the same reactor or in different reactors. In the case where they are carried out in the same reactor, an intermediate injection of the hydrocarbon liquid feedstock is advantageously carried out between the different catalytic beds.
  • the reactor comprises a plurality of catalytic beds, the first catalytic beds comprising the hydrocracking catalyst (s) and the following catalytic beds comprising the hydrotreatment catalyst (s).
  • the hydrotreatment stage f) advantageously operates at a pressure greater than the pressure of the effluent resulting from the hydrocracking step a).
  • At least a portion and preferably all of the effluent from the hydrotreating step f) may advantageously be recycled in the gas / liquid separation step b).
  • At least a portion and preferably all of the effluent from step f) of hydrotreating can advantageously be sent in a second embodiment.
  • gas / liquid separation step for producing a liquid effluent and a gaseous effluent comprising at least hydrogen.
  • said second gas / liquid separation step is carried out in a high temperature high pressure separator operating at a pressure and a temperature compatible with the temperature and the outlet pressure of step f).
  • Said second separation step is preferably carried out at a temperature of between 200 and 390 ° C. under a pressure of between 2 and 16 MPa.
  • liquid effluent from the second separation step may advantageously be recycled in the hydrocracking step e) and / or in the hydrotreating step f).
  • the gaseous effluent comprising at least hydrogen from the second separation step may advantageously be sent in the compression step c).
  • the process uses two gas / liquid separators and a single compressor on the hydrogen recycle loop, as well as a single supplemental hydrogen compressor, which reduces the cost of the installation. .
  • the gaseous effluent comprising at least hydrogen from the second separation step can be sent in a second compression step before its recycle in step e) and / or in step f) .
  • the figure 1 illustrates a particular embodiment of the invention.
  • the hydrocarbon feedstock of the DSV or VGO type (1) enters a hydrocracking section A of step a) corresponding to the first hydrocracking stage.
  • Said section may comprise one or two hydrocracking reactors R1 and / or R2 (not shown in the figure).
  • the effluent (2) from step a) is sent to a gas / liquid separator B of step b) for isolating a gaseous flow comprising hydrogen (7).
  • the gaseous effluent (7) is sent to a recycle compressor C, it is mixed with a feed stream (11) made of hydrogen and then recycled to the hydrocracking reactor via the flow (8).
  • the liquid effluent (3) from the separator B feeds a fractionation column D of step d).
  • An effluent comprising light cuts (10), a gasoline cut (9), and a middle distillate cut (8) corresponding to the gas oil and kerosene are separated in the fractionation column.
  • An unconverted fraction fraction called UCO fraction (UnConverted-Oil) (12) is also separated and sent via the stream (4) in a second hydrocracking section E of step e).
  • Said hydrocracking section E comprises a hydrocracking reactor R3 (no shown in the figure).
  • a purge (13) is implemented on the flow of the unconverted liquid fraction from step d).
  • a hydrocarbon liquid feed (12) of diesel type is injected downstream of the hydrocracking section of the UCO E of step e) and is treated in a hydrodesulfurization section F of step f) mixed with the effluent from the hydrocracking section E, ie the hydrocracked UCO (5).
  • Example 1a comparative: dedicated processes
  • This example is a comparative base case in which the hydrocracking processes of DSV or VGO and hydrodesulfurization of gas oils (GO) are carried out in two separate dedicated processes.
  • the hydrocracking unit processes a vacuum gas oil charge (VGO) and the diesel fuel unit HDS processes a diesel fuel charge (GO) described in Table 1: Table 1 Type VGO GO Debit t / h 49 51 Density t / m 3 0.92 0.83 PI TBP ° C 300 47 PF TBP ° C 552 416 S wt% 2.18 0.68 NOT wtppm 1800 210
  • the feed GO is injected into a preheating stage and then into a hydrotreatment reactor under the following conditions set out in Table 2: Table 2 Reactor HDS GO Temperature ° C 336 Partial pressure H 2 MPa 4 CoMo on alumina Catalyst HR1246 VVH h-1 1.04
  • the catalyst used is a CoMo catalyst on alumina type HR1246 sold by the company Axens.
  • the diesel HDS process is then composed of a high-pressure heat recovery and separation train including a recycle compressor and allowing the separation of hydrogen, sulfur and nitrogen compounds and other components.
  • the desulfurized effluent fed to a steam stripper to separate hydrogen sulphide and naphtha.
  • the final diesel effluent has the following properties set out in Table 3: Table 3 Type GO Debit t / h 46 Density t / m3 0.82 PI TBP ° C 151 PF TBP ° C 450 S wtppm 10.00 NOT wtppm 2
  • VGO feed is injected into a preheating stage and then into a hydrotreatment reactor under the following conditions set out in Table 4:
  • the catalyst used is a CoMo catalyst on alumina type HR1058 sold by the company Axens.
  • the catalyst used is a metal on zeolite catalyst of the HYK742 type sold by the company Axens.
  • R1 and R2 constitute the first stage of the hydrocracker, the R2 effluent is then sent to a separation stage composed of a heat recovery train and high pressure separation including a recycle compressor and to separate the reactor.
  • a separation stage composed of a heat recovery train and high pressure separation including a recycle compressor and to separate the reactor.
  • hydrogen, hydrogen sulphide and ammonia and on the other hand the effluent supplying a stripper and then an atmospheric fractionation column in order to separate streams concentrated in H 2 S, naphtha, kerosene, diesel a the desired specification, and an unconverted heavy stream.
  • This unconverted heavy stream is injected into a preheating stage and then into a hydrocracking reactor R3 constituting the second hydrocracking step.
  • This reactor R3 is operated under the following conditions set out in Table 6: Table 6 Reactor R3 Temperature ° C 345 Partial pressure H 2 MPa 12.5 Metal on amorphous silica-alumina Catalyst HDK766 VVH h-1 3
  • the catalyst used is an amorphous silica-alumina metal catalyst of the HDK766 type sold by the company Axens.
  • the effluent of R3 is then injected into the high-pressure separation stage downstream of the first hydrocracking stage and recycled.
  • the mass flow rate at the inlet of the reactor R3 is equal to the mass flow rate of the charge VGO, a purge corresponding to 2% by mass of the flow rate of the charge VGO is taken as the bottom of fractionation on the unconverted oil flow.
  • the distillate cut produced in the hydrocracker and recovered from the fractionation column is in accordance with Euro V specifications, in particular it has less than 10 ppm sulfur by weight.
  • the average distillate yield of this process is 85% by mass, for an overall conversion of 98% by mass of hydrocarbons whose boiling point is greater than 380 ° C.
  • the total volume of catalyst required for this scheme is 147m 3 .
  • Example 1b Comparative: Co-treatment of a DSV Filler and a Diesel Fuel Filler in a Two-Step Hydrocracking Process
  • This example is a comparative base case in which the hydrocracking reactions of DSV or VGO and hydrodesulfurization of gas oils (GO) are carried out in a single two-stage hydrocracking process (co-treatment of the two charges).
  • the hydrocracking unit processes a vacuum distillate feedstock (VGO) mixed with a gas oil feedstock (GO) identical to those used in Example 1a).
  • VGO vacuum distillate feedstock
  • GO gas oil feedstock
  • the mixture of the two fillers VGO and GO is injected in a preheating stage and then in a hydrotreating reactor R1 operating under conditions identical to those used in Table 4 of Example 1a).
  • R1 and R2 constitute the first stage of the hydrocracker, the effluent from the reactor R2 is then sent to a separation stage composed of a heat recovery train and high pressure separation including a recycle compressor and to separate on the one hand hydrogen, hydrogen sulphide and ammonia and on the other hand the effluent supplying a stripper and then an atmospheric fractionation column in order to separate streams concentrated in H 2 S, naphtha, kerosene, diesel to the desired specification, and an unconverted heavy stream.
  • a separation stage composed of a heat recovery train and high pressure separation including a recycle compressor and to separate on the one hand hydrogen, hydrogen sulphide and ammonia and on the other hand the effluent supplying a stripper and then an atmospheric fractionation column in order to separate streams concentrated in H 2 S, naphtha, kerosene, diesel to the desired specification, and an unconverted heavy stream.
  • This unconverted heavy stream is injected into a preheating stage and then into a hydrocracking reactor R3 constituting the second hydrocracking step.
  • This reactor R3 is operated under the same conditions as those used in Example 1a) and are described in Table 6:
  • the reactor effluent R3 is then injected into the high pressure separation stage downstream of the first hydrocracking stage and recycled.
  • the mass flow rate at the inlet of the reactor R3 is equal to the mass flow rate of the charge VGO, a purge corresponding to 2% by mass of the flow rate of the charge VGO is taken as the bottom of fractionation on the unconverted oil flow.
  • the distillate cut produced in the hydrocracker and recovered from the fractionation column is in accordance with Euro V specifications, in particular it has less than 10 ppm sulfur by weight.
  • the average distillate yield of this process is 80% by mass, for an overall conversion of 98% by mass of hydrocarbons whose boiling point is greater than 380 ° C.
  • the total volume of catalyst required for this scheme is 110m 3 .
  • This example is a diagram according to the invention in which the hydrodesulphurization of gas oils takes place in co-processing with the hydrocracking second stage effluent (thus with hydrocracked UCO).
  • This scheme therefore consists of a single hydrocracker two stages (there is no dedicated process for the hydrodesulfurization of diesel).
  • the first step of method a) is exactly the same as the first step according to example 1.
  • R1 and R2 operate on the same pure VGO or DSV feed described in Table 1 under the same operating conditions as in Tables 4 and 5.
  • the effluent from the reactor R2 is then sent to a separation step b) composed of a high-pressure heat recovery and separation train including a recycle compressor (step c) and making it possible to separate, on the one hand, the hydrogen, hydrogen sulphide and ammonia and secondly the effluent supplying a stripper and an atmospheric fractionation column (step d) in order to separate streams concentrated in H 2 S, naphtha, kerosene, diesel fuel at the desired specification, and a non-converted heavy liquid fraction (UCO) having a boiling point greater than 380 ° C.
  • This unconverted heavy stream is injected into a preheating stage and then into a hydrocracking reactor R3 constituting the second hydrocracking step e).
  • This reactor is operated under the following conditions listed in Table 7: Table 7 Reactor R3 Temperature ° C 345 Partial pressure H 2 MPa 13 Metal on amorphous silica-alumina Catalyst HDK766 VVH h-1 2.8
  • the catalyst used is an amorphous silica-alumina metal catalyst of the HDK766 type sold by the company Axens.
  • the reactor effluent R3 is then mixed with a GO load identical to that of Example 1 described in Table 1.
  • This GO feedstock was preheated by a means known to those skilled in the art, by thermal integration with a feedstock. other process flow.
  • the effluent mixture of the reactor R3 and the feed GO is then injected into a hydrotreating reactor R4 (step f) with the target is the desulfurization of the GO load.
  • the operating conditions of this reactor are as set out in Table 8: Table 8 Reactor R4 Temperature ° C 385 Partial pressure H 2 MPa 12.5 NiMo on alumina Catalyst HR1058 VVH h-1 5.4
  • the catalyst used is a NiMo catalyst on alumina type HR1058 sold by the company Axens.
  • the reactor effluent R4 (step f) is then injected into the high pressure separation step b) downstream of the first hydrocracking step a) and recycled.
  • the mass flow rate at the inlet of the reactor R3 is equal to the mass flow rate of the charge VGO, a purge corresponding to 1% by mass of the flow rate of the charge VGO is taken as the bottom of fractionation on the unconverted oil flow.
  • the distillate fraction produced recovered from the fractionation column is in accordance with the Euro V specification, in particular it has less than 10 ppm sulfur by weight.
  • the average distillate yield of this process is 85% by mass, for an overall conversion of 99% by mass of hydrocarbons whose boiling point is greater than 380 ° C.
  • the total volume of catalyst required for this scheme is 78m 3 .
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FR3107530B1 (fr) * 2020-02-21 2022-02-11 Ifp Energies Now Procede optimise de traitement d’huiles de pyrolyse de plastiques en vue de leur valorisation
CN112391197B (zh) * 2020-11-10 2022-08-23 洛阳瑞泽石化工程有限公司 一种悬浮床渣油加氢裂化系统及方法
FR3136477A1 (fr) 2022-06-14 2023-12-15 IFP Energies Nouvelles Procédé d'hydrocraquage avec gestion du recyclage optimisée pour la production de naphta

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FR2907459A1 (fr) * 2006-10-24 2008-04-25 Inst Francais Du Petrole Procede et installation de conversion de fractions lourdes petrolieres en lit fixe avec production integree de distillats moyens a tres basse teneur en soufre.
WO2008081100A2 (fr) * 2006-12-21 2008-07-10 Institut Francais Du Petrole Procede de conversion de charges issues de sources renouvelables pour produire des bases carburants gazoles de faible teneur en soufre et de cetane ameliore
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US8158070B1 (en) * 2011-03-31 2012-04-17 Uop Llc Apparatus for hydroprocessing two streams
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Cited By (13)

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WO2020144097A1 (fr) * 2019-01-09 2020-07-16 IFP Energies Nouvelles Procede d'hydrocraquage en deux etapes comprenant une etape d'hydrogenation en aval de la deuxieme etape d'hydrocraquage pour la production de distillats moyens
FR3091535A1 (fr) * 2019-01-09 2020-07-10 IFP Energies Nouvelles Procede d’hydrocraquage en deux etapes comprenant une etape d'hydrogenation en aval de la deuxieme etape d’hydrocraquage pour la production de distillats moyens
FR3091534A1 (fr) * 2019-01-09 2020-07-10 IFP Energies Nouvelles Procede d’ hydrocraquage en deux etapes pour la production de naphta comprenant une etape d’hydrogenation mise en œuvre en aval de la deuxieme etape d’hydrocraquage
FR3091533A1 (fr) * 2019-01-09 2020-07-10 IFP Energies Nouvelles Procede d’ hydrocraquage en deux etapes pour la production de naphta comprenant une etape d’hydrogenation mise en œuvre en amont de la deuxieme etape d’hydrocraquage
FR3091537A1 (fr) * 2019-01-09 2020-07-10 IFP Energies Nouvelles Procede d’hydrocraquage en une etape comprenant une etape d'hydrogenation en amont ou en aval de l’etape d’hydrocraquage pour la production de distillats moyens
WO2020144095A1 (fr) * 2019-01-09 2020-07-16 IFP Energies Nouvelles Procede d' hydrocraquage en deux etapes pour la production de naphta comprenant une etape d'hydrogenation mise en œuvre en aval de la deuxieme etape d'hydrocraquage
FR3091536A1 (fr) * 2019-01-09 2020-07-10 IFP Energies Nouvelles Procede d’hydrocraquage en une etape comprenant une etape d'hydrogenation en amont ou en aval de l’etape d’hydrocraquage pour la production de naphta
US10982157B2 (en) 2019-01-09 2021-04-20 IFP Energies Nouvelles Two-step hydrocracking process for the production of naphtha comprising a hydrogenation step carried out upstream of the second hydrocracking step
US11767479B2 (en) 2019-01-09 2023-09-26 IFP Energies Nouvelles Two-stage hydrocracking process for producing naphtha, comprising a hydrogenation stage implemented downstream of the second hydrocracking stage
FR3101082A1 (fr) 2019-09-24 2021-03-26 IFP Energies Nouvelles Procédé intégré d’hydrocraquage en lit fixe et d’hydroconversion en lit bouillonnant avec une séparation gaz/liquide améliorée
WO2021058289A1 (fr) 2019-09-24 2021-04-01 IFP Energies Nouvelles Procédé intégré d'hydrocraquage en lit fixe et d'hydroconversion en lit bouillonnant avec une séparation gaz/liquide améliorée
CN114402056A (zh) * 2019-09-24 2022-04-26 Ifp 新能源公司 具有改进的液/气分离的用于固定床加氢裂化和沸腾床加氢转化的集成方法
FR3104606A1 (fr) 2019-12-17 2021-06-18 IFP Energies Nouvelles Procédé intégré d’hydrocraquage en lit fixe et d’hydroconversion en lit bouillonnant avec un recyclage de l’hydrogène optimisé

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CN109135825B (zh) 2021-12-31
BR102018011832A2 (pt) 2019-01-15
FR3067717A1 (fr) 2018-12-21
KR20180137410A (ko) 2018-12-27
TW201906993A (zh) 2019-02-16
CA3008093A1 (fr) 2018-12-16
TWI800512B (zh) 2023-05-01
US20180362864A1 (en) 2018-12-20
CN109135825A (zh) 2019-01-04
EP3415588B1 (de) 2020-05-13
FR3067717B1 (fr) 2020-11-13
DK3415588T3 (da) 2020-08-10
BR102018011832B1 (pt) 2022-10-25
US10752848B2 (en) 2020-08-25

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