WO2019106921A1 - Procédé de production d'une huile hydrocarbonée - Google Patents

Procédé de production d'une huile hydrocarbonée Download PDF

Info

Publication number
WO2019106921A1
WO2019106921A1 PCT/JP2018/035161 JP2018035161W WO2019106921A1 WO 2019106921 A1 WO2019106921 A1 WO 2019106921A1 JP 2018035161 W JP2018035161 W JP 2018035161W WO 2019106921 A1 WO2019106921 A1 WO 2019106921A1
Authority
WO
WIPO (PCT)
Prior art keywords
oil
feedstock
hydrodesulfurization
calculated
catalyst
Prior art date
Application number
PCT/JP2018/035161
Other languages
English (en)
Japanese (ja)
Inventor
徹 ▲高▼村
康一 松下
Original Assignee
Ｊｘｔｇエネルギー株式会社
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Ｊｘｔｇエネルギー株式会社 filed Critical Ｊｘｔｇエネルギー株式会社
Publication of WO2019106921A1 publication Critical patent/WO2019106921A1/fr

Links

Images

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
    • C10G11/00—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils
    • C10G11/14—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts
    • C10G11/18—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts according to the "fluidised-bed" technique
    • 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
    • C10G69/00—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process
    • C10G69/02—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only
    • C10G69/04—Treatment of hydrocarbon oils by at least one hydrotreatment process and at least one other conversion process plural serial stages only including at least one step of catalytic cracking in the absence of hydrogen

Definitions

  • the present invention relates to a method of producing a hydrocarbon oil.
  • a desulfurized heavy oil in which a vacuum gas oil (Vacuum Gas Oil: VGO) is obtained by vacuum distillation of atmospheric residual oil, and the sulfur content is reduced by hydrotreating the vacuum gas oil.
  • a method of obtaining light hydrocarbons and light hydrocarbons mainly composed of gasoline by fluid catalytic cracking (FCC) of desulfurized heavy oil is disclosed.
  • Light olefins are compounds with higher added value than heavy oils and are used as feedstocks for gasoline bases such as alkylates or methyl-t-butyl ether.
  • CCG Catalytic Cracked Gasoline
  • LCO Light Cycle Oil
  • the present invention has been made in view of the problems of the above-mentioned prior art, and prior to fluid catalytic cracking, the hydrodesulfurization of a feedstock oil containing atmospheric residual oil is carried out while maintaining the reduction effect of sulfur content.
  • An object of the present invention is to provide a method for producing a hydrocarbon oil which can sufficiently reduce the content of metals in the oil.
  • the method for producing a hydrocarbon oil comprises the steps of obtaining a desulfurized heavy oil by hydrodesulfurization of a first feedstock oil containing atmospheric residual oil, and a second feedstock oil containing desulfurized heavy oil. of the fluid catalytic cracking, obtaining a product, with a liquid hourly space velocity in the hydrogenation desulfurization, and at 0.3h -1 or 1.0 h -1 or less, the deasphalted oil occupying the first feedstock The proportion is 30% by volume or more and 75% by volume or less, and the content of asphaltene in the first raw material oil is 0% by mass or more and 1% by mass or less.
  • the ratio of vacuum residue to the first feedstock oil may be 50% by volume or more and 85% by volume or less.
  • the content of metals in the feedstock oil is sufficiently reduced while maintaining the reduction effect of the sulfur content by hydrodesulfurization of the feedstock oil containing atmospheric residual oil.
  • FIG. 1 shows the relationship between the volume ratio of vacuum residue (VR) to the first feedstock oil and the metal removal rate in the hydrodesulfurization of the first feedstock oil.
  • FIG. 2 shows the relationship between the content of asphaltene in the first feedstock oil and the demetallization rate in the hydrodesulfurization of the first feedstock oil.
  • FIG. 3 shows the relationship between the reaction temperature T for hydrodesulfurization of the first feedstock oil and the content of metals (nickel and vanadium) in the desulfurized heavy oil obtained by hydrodesulfurization.
  • FIG. 4 shows the relationship between the desulfurization rate in the hydrodesulfurization of the first feedstock oil and the demetalization rate in the hydrodesulfurization.
  • FIG. 5 shows the relationship between the reaction temperature T for hydrodesulfurization of the first feedstock oil and the reaction rate constant kM of the demetalization reaction in the hydrodesulfurization.
  • FIG. 6 shows the relationship between the liquid hourly space velocity LHSV in hydrodesulfurization of the first feedstock oil and the demetallization rate in the hydrodesulfurization.
  • a step of obtaining a desulfurized heavy oil by hydrodesulfurization of a first feedstock oil containing atmospheric residual oil, and a flow of a second feedstock oil containing the desulfurized heavy oil Obtaining the product by catalytic decomposition.
  • hydrodesulfurization desulfurization reaction and demetallation reaction occur.
  • Hydrodesulfurization may be rephrased as residual oil desulfurization (RDS), for example.
  • the desulfurized heavy oil may be rephrased as RDS Bottom oil (RDS-BTM) obtained by distillation of RDS product oil.
  • the ratio of deasphalted oil (De-Asphalted Oil: DAO) to the first feedstock oil is 30% by volume or more and 75% by volume or less.
  • the metal content is maintained while maintaining the reduction effect of the sulfur content.
  • a sufficiently reduced desulfurized heavy oil can be obtained.
  • the liquid space velocity is about 0.3 h -1 and the reaction temperature is about 370 ° C.
  • the proportion of deasphalted oil in the first feedstock oil may be 35% by volume or more and 70% by volume or 46% by volume or more and 54% by volume or less.
  • the ratio of deasphalted oil to the first feedstock oil exceeds 75% by volume, the deterioration of the catalyst tends to be quick.
  • “Deterioration of the catalyst” means degradation of the hydrogen purification catalyst (demetallization catalyst and desulfurization catalyst) (particularly degradation of the desulfurization catalyst).
  • the sulfur content may be, for example, a sulfur-containing compound containing sulfur and a hydrocarbon.
  • the sulfur content in the desulfurized heavy oil may be measured, for example, according to JIS K 2541 "Crude oil and petroleum products-Sulfur content test method".
  • the metal component may be, for example, a metal-containing compound containing a metal and a hydrocarbon, or may be a simple metal.
  • the metal constituting the metal component is, for example, vanadium or nickel.
  • the structure of the metal-containing compound is not particularly limited. For example, in a metal-containing compound, a hydrocarbon and a metal may form a chemical bond (for example, a coordinate bond). In the metal-containing compound, the hydrocarbon may coat fine particles of metal.
  • the hydrocarbon constituting the metal-containing compound is not particularly limited, and may be, for example, a chain hydrocarbon or an isomer thereof, a cyclic hydrocarbon, a heterocyclic compound, an aromatic hydrocarbon or the like.
  • the heterocyclic compound may be, for example, porphyrin.
  • the metal-containing compound may be, for example, a metal porphyrin complex.
  • the contents of nickel and vanadium in the desulfurized heavy oil may be measured, for example, by wavelength dispersive X-ray fluorescence spectrometry (XRF method).
  • the density of the first feedstock (mixed oil) including atmospheric residual oil and deasphalted oil tends to be higher than the density of atmospheric residual oil, and in general, the metal content in the dense feedstock oil is It is difficult to remove by hydrodesulfurization as compared with the metal component in the low feedstock oil.
  • a desulfurized heavy oil (a second feedstock for fluid catalytic cracking) having a reduced metal content is obtained from a first feedstock including atmospheric residual oil and deasphalted oil.
  • the desulfurization weight whose metal content has been sufficiently reduced by subjecting deasphalted oil, which was conventionally difficult to be utilized sufficiently in fluid catalytic cracking, to hydrodesulfurization together with atmospheric residual oil, is achieved.
  • a quality oil is prepared. It is possible to obtain a gasoline fraction and a light oil fraction derived from deasphalted oil, which was conventionally difficult to use as a raw material for a gasoline fraction and a gas oil fraction, by fluid catalytic cracking of the second feedstock including the desulfurized heavy oil. It will be possible.
  • the low market value deasphalted oil is used together with the atmospheric residual oil as a raw material of hydrocarbon oil having high market value (such as gasoline fraction and gas oil fraction). it can. Moreover, according to the present embodiment, it is also possible to suppress the formation of coke in fluid catalytic cracking. Cork is a carbonaceous solid.
  • the deasphalted oil contained in the first feedstock may be obtained by solvent deasphalting (Solvent De-Asphalting: SDA) of vacuum resid.
  • the deasphalted oil may be rephrased as an extracted oil (a solvent deasphalted oil) in SDA.
  • the solvent used for deasphalting may be, for example, at least one selected from the group consisting of propane, normal butane, isobutane, normal pentane, isopentane and normal hexane.
  • the first feedstock may be prepared by mixing deasphalted oil and atmospheric residuum.
  • a vacuum residue is obtained by vacuum distillation of an atmospheric residue.
  • Atmospheric residual oil is obtained by atmospheric distillation of crude oil.
  • the crude oil may be, for example, at least one selected from the group consisting of, but not limited to, petroleum-based crude oil, synthetic crude oil derived from oil sands, and bitumen-modified oil.
  • V DAO / V 1 When the volume of the deasphalted oil contained in the first feedstock oil is represented as V DAO and the volume of the entire first feedstock oil is represented as V 1, V DAO / V 1 is 0.30 or more and 0.75 or less 0.35 or more and 0.70 or less, or 0.46 or more and 0.54 or less.
  • V DAO / V 1 the ratio of the gasoline fraction and gas oil fraction derived from deasphalted oil increases as V DAO / V1 increases.
  • V.sub.DAO / V.sub.1 decreases, dry gas and coke are easily generated in the fluid catalytic cracking of the second feedstock.
  • the first feedstock may consist of deasphalted oil and atmospheric residual oil.
  • V1 when the volume of normal pressure residual oil contained in the first feedstock is denoted as V AR , V1 may be equal to V DAO + V AR and V DAO / V1 is V DAO / (V DAO + V AR ) May be equal to Therefore, V DAO / (V DAO + V AR ) may be 0.30 or more and 0.75 or less, 0.35 or more and 0.70 or less, or 0.46 or more and 0.54 or less.
  • the volume fraction of deasphalted oil in the first feedstock (V DAO / V1) may be controlled based on the mixing ratio of deasphalted oil and atmospheric residual oil.
  • the first feedstock may comprise vacuum residuum. That is, according to the present embodiment, the feedstock oil (second feedstock oil) for fluid catalytic cracking can be prepared from the reduced pressure residual oil having a high sulfur content. In other words, according to the present embodiment, it is possible to use an inexpensive reduced pressure residual oil, which tends to be surplus in the conventional process, as a raw material of expensive hydrocarbon oils such as gasoline fractions and light oil fractions.
  • the ratio of the vacuum residue to the first feedstock oil may be 50% to 85% by volume, 55% to 80% by volume, or 65% to 71% by volume.
  • the volume of the vacuum residue oil contained in the first feedstock when it is expressed as V VR, V VR / V1 is 0.5 to 0.85, 0.55 or 0.80 or less, or 0 .65 or more and 0.71 or less.
  • the metal is hydrodesulfurized under the above-mentioned conditions, even though the ratio of the vacuum residue to the first feedstock (V VR / V 1) is high. It is possible to obtain a desulfurized heavy oil having a sufficiently reduced content.
  • the catalyst tends to deteriorate rapidly.
  • At least a portion of the vacuum residuum contained in the first feedstock may be derived from deasphalted oil.
  • Deasphalted oil is a type of vacuum residue.
  • at least a portion of the vacuum residuum contained in the first feedstock may be derived from an atmospheric residuum directly subjected to hydrodesulfurization.
  • Atmospheric residual oil includes, as a constituent fraction thereof, reduced pressure residual oil and reduced pressure gas oil.
  • the volume ratio (V VR / V 1) of the vacuum residue to the first feedstock may be controlled based on the mixing ratio of the deasphalted oil and the atmospheric residue.
  • Liquid hourly space velocity in the hydrogenation desulfurization of the first feedstock is 0.3h -1 or 1.0 h -1 or less.
  • the liquid hourly space velocity is a value obtained by dividing the feed rate (volume flow rate per short time) of the first feedstock to the hydrodesulfurization reactor by the volume of the catalyst (catalyst layer) installed in the reactor. .
  • the desulfurization weight in which the metal content is sufficiently reduced It is possible to obtain a quality oil.
  • liquid hourly space velocity When the liquid hourly space velocity is less than 0.3 h -1 , productivity declines due to a decrease in throughput of the reactor, or deterioration of the flow state of the first feedstock oil in the reactor causes uneven flow in the catalyst layer. There is a tendency to get up.
  • the liquid hourly space velocity exceeds 1.0 h -1 , the concentration of sulfur and metal in the desulfurized heavy oil tends to increase due to the decrease in contact time. Liquid hourly space velocity in the hydrodesulfurization, 0.3h -1 or 0.6 h -1 or less, or 0.3h -1 more 0.5h -1 may be less.
  • the content of asphaltenes in the first feedstock oil is 0% by mass or more and 1% by mass or less.
  • Asphaltene may be, for example, a component insoluble in pentane and soluble in toluene among asphalts.
  • the content of asphaltenes in the first feedstock oil is greater than 1% by mass, the content of metals in the desulfurized heavy oil tends to be high.
  • the content of asphaltene in the first feedstock oil is higher than 1% by mass, coke is easily generated in hydrodesulfurization and fluid catalytic cracking.
  • the yield of the gasoline fraction and the gas oil fraction in the fluid catalytic cracking tends to decrease.
  • the lower limit of the content of asphaltenes in the first feedstock oil is not particularly limited.
  • the content of asphaltenes in the first raw material oil may be, for example, 0.08% by mass or more and 0.22% by mass.
  • the content of asphaltenes in the first feedstock oil is the selection of crude oil used for preparation of the first feedstock oil, distillation conditions of crude oil, selection of fractions obtained by distillation, method of deburring of fractions, conditions of deburring Or, it is freely adjusted by the mixing ratio etc. of a plurality of kinds of fractions.
  • Asphaltene content may be measured, for example, by IP-143 (ASTM D6560) "Determination of Asphaltenes in Crude Petroleum and Petroleum Products".
  • the pressure in the reactor where the hydrodesulfurization of the first raw material oil is performed may be 10 MPa or more and 20 MPa or less, or 10 MPa or more and 15 MPa or less.
  • the pressure is less than 10 MPa, coking tends to deteriorate the activity of the desulfurization catalyst and the demetallization catalyst.
  • the pressure exceeds 20 MPa, the equipment investment and the increase in variable costs for the hydrogen supply become very large.
  • the output of the compressor is insufficient and the supply amount of hydrogen tends to be low, whereby the processing amount of hydrodesulfurization tends to be reduced.
  • the hydrodesulfurization hydrogen / oil ratio is preferably 3000-8000 scfb (standard cubic feet per barrel), more preferably 4000-7000 scfb, even more preferably 5000-6000 scfb. If it is less than 3000 scfb, it is not preferable because deterioration of the catalyst tends to progress. In addition, even if it exceeds 8000 scfb, the influence on the catalyst deterioration tends to disappear, which is not preferable.
  • the reaction temperature T for hydrodesulfurization may be 330 ° C. or more and 410 ° C. or less, 360 ° C. or more and 400 ° C. or less, or 364 ° C. or more and 384 ° C. or less.
  • the reaction temperature T for hydrodesulfurization can be rephrased as the average temperature of the catalyst (catalyst layer) installed in the hydrodesulfurization reactor.
  • the catalyst used for hydrodesulfurization of the first feedstock oil may include not only the desulfurization catalyst but also a demetalation catalyst having a function of removing metal components.
  • the first feedstock oil may be brought into contact with the desulfurization catalyst (desulfurizing catalyst layer). That is, using a hydrorefining catalyst (two-stage catalyst layer) combining the first stage metal removal catalyst (catalyst layer) and the second stage desulfurization catalyst (catalyst layer) as a catalyst for hydrodesulfurization of feedstock oil Good.
  • the demetallizing catalyst has a demetallizing activity and a desulfurizing activity, and is a catalyst having a relatively high demetallizing activity as compared to the desulfurizing catalyst.
  • the demetallizing catalyst By placing the desulfurization catalyst downstream of the demetalation catalyst, the demetalation catalyst protects the desulfurization catalyst from metal. Therefore, the demetallizing catalyst must have high performance to remove and capture metal components such as nickel and vanadium contained in the feedstock under hydrodesulfurization conditions.
  • a demetallizing catalyst demetallizing catalyst having resistance to metal components
  • the demetallizing catalyst having such characteristics may be provided, for example, with a porous support and an active metal supported on the support.
  • the demetallizing catalyst support may be, for example, at least one selected from the group consisting of alumina, silica, and silica-alumina.
  • the active metal of the demetallizing catalyst may be, for example, at least one selected from the group consisting of molybdenum, nickel and cobalt.
  • the active metal of the demetallizing catalyst may be only molybdenum, may be a combination of nickel and molybdenum, or may be a combination of cobalt and molybdenum.
  • the demetallation catalyst may further contain phosphorus.
  • the average pore size of the demetallizing catalyst is preferably 13 to 30 nm, and the pore volume of the demetallizing catalyst is 0.7 to 1.4 cm 3 / g
  • the surface area of the demetallizing catalyst is preferably 70 to 200 m 2 / g.
  • the desulfurization catalyst has a desulfurization activity, a denitrification activity and a demetallation activity, and is a catalyst having a relatively high desulfurization activity as compared to the demetalation catalyst. Because of the high desulfurization activity, the resistance of the desulfurization catalyst to metals is inferior to the demetallisation catalyst, so as mentioned above, the desulfurization catalyst is placed downstream of the demetallisation catalyst.
  • the desulfurization catalyst has the ability to highly remove sulfur and nitrogen contained in the feedstock under hydrodesulfurization conditions.
  • the desulfurization catalyst having such characteristics may include, for example, a porous carrier and an active metal supported on the carrier.
  • the desulfurization catalyst support may be, for example, at least one selected from the group consisting of alumina, silica, and silica-alumina.
  • the active metal of the desulfurization catalyst may include, for example, at least one of nickel and cobalt and at least one of molybdenum and tungsten.
  • the active metal of the desulfurization catalyst may be a combination of nickel and molybutene, may be a combination of cobalt and molybutene, or may be a combination of nickel, cobalt and molybutene.
  • the desulfurization catalyst may further contain phosphorus.
  • the surface area of the desulfurization catalyst is preferably larger than that of the metal removal catalyst, and the average pore diameter of the desulfurization catalyst is preferably 8 to 13 nm, and the pore volume of the desulfurization catalyst is 0.4 to 1.0 cm 3
  • the surface area of the desulfurization catalyst is preferably 170 to 250 m 2 / g.
  • the volume of the demetallizing catalyst layer can be 30% by volume or more and 60% by volume or less based on the total value of the volumes of the desulfurizing catalyst layer and the demetallizing catalyst layer.
  • the volume of the demetallizing catalyst layer is 30% by volume or more, the demetallizing reaction in the former stage side (demetallizing catalyst layer side) easily progresses sufficiently, and the inflow to the latter half side of the metal (desulfurizing catalyst layer) It tends to be suppressed, and rapid deterioration of the activity of the desulfurization catalyst layer tends to be suppressed.
  • the volume of the demetallizing catalyst layer is 60% by volume or less, the desulfurization reaction tends to proceed sufficiently, and the concentration of sulfur in the desulfurized heavy oil to be produced tends to be reduced.
  • the second feedstock may consist only of desulfurized heavy oil.
  • the second feedstock may include other oils in addition to the desulfurized heavy oil.
  • the second feedstock may further include desulfurized vacuum gas oil in addition to the desulfurized heavy oil obtained by hydrodesulfurization of the first feedstock.
  • Reduced pressure gas oil is obtained by reduced pressure distillation of atmospheric residue.
  • the desulfurized vacuum gas oil is obtained, for example, by hydrodesulfurization of vacuum gas oil.
  • V DSH volume of the desulfurized heavy oil contained in the secondary feed
  • V DSVGO volume of desulfurized vacuum gas oil contained in the second feedstock
  • V HDSVGO / V DSH May be 0/100 or more and 90/10 or less.
  • the reaction temperature for fluid catalytic cracking of the second feedstock oil may be 500 ° C. or more and 700 ° C. or less.
  • the reaction temperature is 500 ° C. or higher, the decomposition rate tends to be improved, and the yield of the gasoline fraction tends to be improved.
  • the reaction temperature exceeds 700 ° C., the decomposition reaction tends to be promoted and the formation of dry gas and coke tends to be promoted.
  • the catalyst / oil ratio in the fluid catalytic cracking may be 3 [mass / mass] or more and 50 [mass / mass] or less.
  • the catalyst / oil ratio is a value obtained by dividing the catalyst circulation amount (ton / h) by the feed rate of the second feedstock (ton / h).
  • the reaction time (contact time) of fluid catalytic cracking may be from 0.5 seconds to 10 seconds.
  • the reaction time is 0.5 seconds or more, the decomposition rate tends to be improved, and the yield of the gasoline fraction tends to be improved.
  • the reaction time exceeds 10 seconds, the decomposition reaction tends to be promoted and the formation of dry gas and coke tends to be promoted.
  • the mass of steam supplied to the fluid catalytic cracking may be 2 parts by mass or more and 50 parts by mass or less with respect to 100 parts by mass of the second feedstock oil.
  • the pressure in the reactor in which fluid catalytic cracking is performed may be 0.1013 MPa or more and 0.3 MPa or less. If the pressure is less than 0.1013 MPa (standard pressure), the pressure of the gas after decomposition tends to decrease and the operation of the recovery facility tends to be difficult.
  • the pressure exceeds 0.3 MPa the partial pressure of hydrocarbons in the reactor tends to be high, the decomposition rate becomes too high, and the formation of dry gas and coke tends to be promoted.
  • the fluid catalytic cracking of the second feedstock may be conventional fluid catalytic cracking.
  • a fluidizing gas for example, a gaseous second raw material oil
  • innumerable catalyst particles decomposition catalysts
  • the fluidized catalyst particles are raised by the fluidized gas in the riser type reaction tower.
  • the second feedstock oil is decomposed by bringing the catalyst particles into contact with the second feedstock oil in the reaction tower.
  • the catalyst particles used for the catalytic cracking are supplied to the regeneration tower for regeneration, and then reused for catalytic cracking of the second feedstock oil in the reaction tower. That is, catalyst particles are circulated between the regeneration tower and the reaction tower.
  • the fluid catalytic cracking of the second feedstock oil may be High-Severity Fluid Catalytic Cracking (HS-FCC).
  • HS-FCC High-Severity Fluid Catalytic Cracking
  • a downflow reactor is used instead of a riser reactor.
  • high severity fluid catalytic cracking is about the same as conventional fluid catalytic cracking.
  • back mixing is easily suppressed and the reaction time of the decomposition reaction of the second raw material oil tends to be uniform as compared with the riser type reaction column.
  • the cracking catalyst used for fluid catalytic cracking may, for example, comprise an inorganic oxide (matrix component) and a zeolite.
  • the inorganic oxide may be, for example, at least one selected from the group consisting of kaolin, montmorillonite, halloysite, bentonite, alumina, silica, boria, chromia, magnesia, zirconia, titania and silica alumina.
  • the zeolite may be, for example, at least one of natural zeolite and synthetic zeolite.
  • Natural zeolites such as gmelinite, shabasite, dakialdo fluorite, clinoptilolite, hojasite, quafluorite, borofluorite, leupinite, elionite, sodalite, cancrinite, ferrierite, briuester fluorite, offretite, soda fluoride It may be at least one selected from the group consisting of stone and mordenite.
  • Synthetic zeolites are X-type zeolite, Y-type zeolite, USY-type zeolite, A-type zeolite, L-type zeolite, ZK-4 type zeolite, B-type zeolite, E-type zeolite, F-type zeolite, H-type zeolite, H-type zeolite, J-type zeolite, M-type zeolite, Q-type zeolite, T-type zeolite, W-type zeolite, Z-type zeolite, ⁇ -type zeolite, ⁇ -type zeolite, ⁇ -type zeolite, ⁇ -type zeolite, ZSM-5 type zeolite, SAPO-5 type zeolite, SAPO-11 type zeolite and It may be at least one selected from the group consisting of SAPO-34 zeolites.
  • the product obtained by fluid catalytic cracking of the second feedstock oil is separated into multiple components in a recovery facility.
  • the recovery facility may comprise, for example, a plurality of distillation columns, absorbers, compressors, strippers, and heat exchangers.
  • the products are, for example, dry gas, LP gas (LPG), gasoline fraction (CCG), light oil fraction (LCO), bottom fraction (CLarified Oil: CLO) and coke in a distillation column (atmospheric distillation column). It is fractionated.
  • [S] in the following table means the measured value of the content of sulfur in each oil.
  • [Ni] in the following table means the measured value of the content of nickel in each oil.
  • [V] in the following table means the measured value of the vanadium content in each oil.
  • [Asp] in the following table means the measured value of content of asphaltene in each oil.
  • the ratio of VR of each oil in the following table is a value at 538 ° C.
  • the mixed oil 1 was prepared by mixing AR2 and DAO1 in the volume ratio shown in Table 2 below.
  • Mixed oil 2 was prepared by mixing AR2 and DAO2 in the volume ratio shown in Table 2 below.
  • the mixed oil 3 was prepared by mixing AR2 and DAO3 in the volume ratio shown in Table 2 below.
  • the mixed oil 1, the mixed oil 2 and the mixed oil 3 all correspond to the first feedstock in the present invention.
  • Mixed oil 1, mixed oil 2 and mixed oil 3 each had the properties shown in Table 1 below.
  • Example 1 As the first feedstock oil of Example 1, mixed oil 1 was used. A catalyst layer comprising 44% by volume of a demetalation catalyst containing nickel and molybutene and 56% by volume of a desulfurization catalyst containing nickel, cobalt and molybutene Mo was placed in the reactor. The mixed oil 1 was hydrodesulfurized by supplying the mixed oil 1 and hydrogen gas into the reactor, and bringing the mixed oil 1 into contact with the catalyst layer under a hydrogen atmosphere. The hydrogen / oil ratio was adjusted to 5500 scfb. The pressure in the reactor was adjusted to 14.4 MPa. Desulfurized heavy oil was obtained by hydrodesulfurization of the mixed oil 1. The liquid space velocity LHSV in hydrodesulfurization was adjusted to the values shown in Table 3 below.
  • the reaction temperature T of hydrodesulfurization was adjusted.
  • the reaction temperature T for hydrodesulfurization was a value shown in Table 3 below.
  • the demetalization rate in the hydrodesulfurization of Example 1 was calculated by the following formula 1.
  • [M] is an actual measurement value of the metal content in the first feedstock oil (that is, [Ni] + [V] of the first feedstock oil).
  • [POM] is the measured value of the metal content in the desulfurized heavy oil (that is, [Ni] + [V] of the desulfurized heavy oil).
  • the demetalization rate of Example 1 was a value shown in Table 3 below.
  • Metal removal rate 100 ⁇ ([M]-[POM]) / [M] (1)
  • Fluid catalytic cracking of the second feedstock was carried out by bringing the second feedstock comprising only desulfurized heavy oil into contact with the cracked catalyst bed in the reactor in the presence of steam.
  • the product obtained by fluid catalytic cracking was fractionated to obtain dry gas, LP gas (LPG), gasoline fraction (CCG), light oil fraction (LCO), bottom fraction (CLO) and coke.
  • Example 2 In Example 2, mixed oil 2 was used in place of mixed oil 1 as the first feedstock oil.
  • the reaction temperature T of the hydrodesulfurization of Example 2 was a value shown in Table 3 below.
  • the hydrodesulfurization and fluid catalytic cracking of Example 2 were carried out in the same manner as Example 1 except for these matters.
  • the metal removal rate of Example 2 calculated by the same method as Example 1 was a value shown in Table 3 below.
  • Example 3 In Example 3, mixed oil 3 was used in place of mixed oil 1 as the first raw material oil.
  • the reaction temperature T of the hydrodesulfurization of Example 3 was a value shown in Table 3 below.
  • the hydrodesulfurization and fluid catalytic cracking of Example 3 were carried out in the same manner as in Example 1 except for these matters.
  • the metal removal rate of Example 3 calculated by the same method as Example 1 was a value shown in Table 3 below.
  • Comparative Example 1 In Comparative Example 1, only normal-pressure residual oil AR1 was used in place of mixed oil 1 as the first raw material oil.
  • the reaction temperature T of the hydrodesulfurization of Comparative Example 1 was a value shown in Table 3 below.
  • the hydrodesulfurization and fluid catalytic cracking of Comparative Example 1 were carried out in the same manner as in Example 1 except for these matters.
  • the metal removal rate of Comparative Example 1 calculated by the same method as Example 1 was a value shown in Table 3 below.
  • Comparative Example 2 In Comparative Example 2, only normal-pressure residual oil AR2 was used in place of mixed oil 1 as the first raw material oil.
  • the reaction temperature T of the hydrodesulfurization of Comparative Example 2 was a value shown in Table 3 below.
  • the hydrodesulfurization and fluid catalytic cracking of Comparative Example 2 were carried out in the same manner as in Example 1 except for these matters.
  • the metal removal rate of Comparative Example 2 calculated by the same method as that of Example 1 was a value shown in Table 3 below.
  • Example 1A, 1B, 1C The reaction temperature T and the liquid space velocity LHSV of Example 1A were the values shown in Table 4 below.
  • the hydrodesulfurization and fluid catalytic cracking of Example 1A were performed in the same manner as in Example 1 except for these matters.
  • the sulfur content and metal content of the desulfurized heavy oil of Example 1A were values shown in Table 4 below.
  • the desulfurization rate in the hydrodesulfurization of Example 1A was calculated by the following formula 2.
  • the following [S] is an actual measurement value of the sulfur content in the first feedstock oil.
  • the following [POS] means the measured value of the sulfur content in the desulfurized heavy oil.
  • the desulfurization rate of Example 1 was a value shown in Table 5 below.
  • the demetalization rate of Example 1A calculated by the same method as Example 1 was a value shown in Table 5 below.
  • Desulfurization rate 100 ⁇ ([S]-[POS]) / [S] (2)
  • the reaction temperature T of Example 1 B was a value shown in Table 4 below.
  • the hydrodesulfurization and fluid catalytic cracking of Example 1B were carried out in the same manner as Example 1A except for the reaction temperature T.
  • the contents of sulfur content and metal content in the desulfurized heavy oil of Example 1 B were the values shown in Table 4 below.
  • the desulfurization ratio of Example 1B calculated by the same method as that of Example 1A was a value shown in Table 5 below.
  • the metal removal rate of Example 1B calculated by the same method as Example 1 was a value shown in Table 5 below.
  • KS of Example 1B calculated by the same method as Example 1A was a value shown in Table 5 below.
  • the kM of Example 1B calculated by the same method as that of Example 1A was a value shown in Table 5 below.
  • the reaction temperature T of Example 1C was a value shown in Table 4 below.
  • the hydrodesulfurization and fluid catalytic cracking of Example 1C were carried out in the same manner as Example 1A except for the reaction temperature T.
  • the contents of sulfur content and metal content in the desulfurized heavy oil of Example 1C were values shown in Table 4 below.
  • the desulfurization ratio of Example 1C calculated by the same method as that of Example 1A was a value shown in Table 5 below.
  • the metal removal rate of Example 1C calculated by the same method as Example 1 was a value shown in Table 5 below.
  • KS of Example 1C calculated by the same method as Example 1A was a value shown in the following Table 5.
  • the kM of Example 1C calculated by the same method as that of Example 1A was a value shown in Table 5 below.
  • Example 2A, 2B, 2C The reaction temperature T and the liquid space velocity LHSV of Example 2A were the values shown in Table 4 below.
  • the hydrodesulfurization and fluid catalytic cracking of Example 2A were carried out in the same manner as in Example 2 except for these matters.
  • the sulfur content and the metal content of the desulfurized heavy oil of Example 2A were the values shown in Table 4 below.
  • the desulfurization ratio of Example 2A calculated by the same method as that of Example 1A was a value shown in Table 5 below.
  • the metal removal rate of Example 2A calculated by the same method as Example 1 was a value shown in Table 5 below.
  • KS of Example 2A calculated by the same method as Example 1A was a value shown in Table 5 below.
  • the kM of Example 2A calculated by the same method as that of Example 1A was a value shown in Table 5 below.
  • the reaction temperature T of Example 2B was a value shown in Table 4 below.
  • the hydrodesulfurization and fluid catalytic cracking of Example 2B were performed in the same manner as Example 2A except for the reaction temperature T.
  • the sulfur content and the metal content of the desulfurized heavy oil of Example 2B were the values shown in Table 4 below.
  • the desulfurization ratio of Example 2B calculated by the same method as that of Example 1A was a value shown in Table 5 below.
  • the metal removal rate of Example 2B calculated by the same method as Example 1 was a value shown in Table 5 below.
  • KS of Example 2B calculated by the same method as Example 1A was a value shown in Table 5 below.
  • the kM of Example 2B calculated by the same method as that of Example 1A was a value shown in Table 5 below.
  • the reaction temperature T of Example 2C was a value shown in Table 4 below.
  • the hydrodesulfurization and fluid catalytic cracking of Example 2C were performed in the same manner as Example 2A except for the reaction temperature T.
  • the sulfur content and metal content of the desulfurized heavy oil of Example 2C were values shown in Table 4 below.
  • the desulfurization ratio of Example 2C calculated by the same method as that of Example 1A was a value shown in Table 5 below.
  • the metal removal rate of Example 2C calculated by the same method as that of Example 1 was a value shown in Table 5 below.
  • KS of Example 2C calculated by the same method as Example 1A was a value shown in the following Table 5.
  • the kM of Example 2C calculated by the same method as that of Example 1A was a value shown in Table 5 below.
  • Examples 3A, 3B, 3C The reaction temperature T and the liquid space velocity LHSV of Example 3A were the values shown in Table 4 below.
  • the hydrodesulfurization and fluid catalytic cracking of Example 3A were carried out in the same manner as in Example 3 except for these matters.
  • the sulfur content and metal content of the desulfurized heavy oil of Example 3A were the values shown in Table 4 below.
  • the desulfurization ratio of Example 3A calculated by the same method as that of Example 1A was a value shown in Table 5 below.
  • the metal removal rate of Example 3A calculated by the same method as Example 1 was a value shown in Table 5 below.
  • KS of Example 3A calculated by the same method as Example 1A was a value shown in Table 5 below.
  • the kM of Example 3A calculated by the same method as that of Example 1A was a value shown in Table 5 below.
  • the reaction temperature T of Example 3B was a value shown in Table 4 below.
  • the hydrodesulfurization and fluid catalytic cracking of Example 3B were performed in the same manner as Example 3A except for the reaction temperature T.
  • the sulfur content and metal content of the desulfurized heavy oil of Example 3B were the values shown in Table 4 below.
  • the desulfurization ratio of Example 3B calculated by the same method as that of Example 1A was a value shown in Table 5 below.
  • the metal removal rate of Example 3B calculated by the same method as Example 1 was a value shown in Table 5 below.
  • KS of Example 3B calculated by the same method as Example 1A was a value shown in Table 5 below.
  • the kM of Example 3B calculated by the same method as that of Example 1A was a value shown in Table 5 below.
  • the reaction temperature T of Example 3C was a value shown in Table 4 below.
  • the hydrodesulfurization and fluid catalytic cracking of Example 3C were carried out in the same manner as Example 3A except for the reaction temperature T.
  • the sulfur content and metal content of the desulfurized heavy oil of Example 3C were values shown in Table 4 below.
  • the desulfurization ratio of Example 3C calculated by the same method as that of Example 1A was a value shown in Table 5 below.
  • the metal removal rate of Example 3C calculated by the same method as Example 1 was a value shown in Table 5 below.
  • KS of Example 3C calculated by the same method as Example 1A was a value shown in Table 5 below.
  • the kM of Example 3C calculated by the same method as Example 1A was a value shown in Table 5 below.
  • the reaction temperature T of Comparative Example 1B was a value shown in Table 4 below.
  • the hydrodesulfurization and fluid catalytic cracking of Comparative Example 1B were performed in the same manner as Comparative Example 1A except for the reaction temperature T.
  • the contents of sulfur content and metal content in the desulfurized heavy oil of Comparative Example 1 B were values shown in Table 4 below.
  • the desulfurization ratio of Comparative Example 1B calculated by the same method as Example 1A was a value shown in Table 5 below.
  • the metal removal rate of Comparative Example 1B calculated by the same method as that of Example 1 was a value shown in Table 5 below.
  • KS of Comparative Example 1B calculated by the same method as Example 1A was a value shown in Table 5 below.
  • the kM of Comparative Example 1B calculated by the same method as Example 1A was a value shown in Table 5 below.
  • the reaction temperature T of Comparative Example 1C was a value shown in Table 4 below.
  • the hydrodesulfurization and fluid catalytic cracking of Comparative Example 1C were performed in the same manner as Comparative Example 1A except for the reaction temperature T.
  • the contents of sulfur content and metal content in the desulfurized heavy oil of Comparative Example 1C were values shown in Table 4 below.
  • the desulfurization rate of Comparative Example 1C calculated by the same method as that of Example 1A was a value shown in Table 5 below.
  • the metal removal rate of Comparative Example 1C calculated by the same method as Example 1 was a value shown in Table 5 below.
  • KS of Comparative Example 1C calculated by the same method as Example 1A was a value shown in Table 5 below.
  • KM of Comparative Example 1C calculated by the same method as Example 1A was a value shown in Table 5 below.
  • the reaction temperature T of Comparative Example 2B was a value shown in Table 4 below.
  • the hydrodesulfurization and fluid catalytic cracking of Comparative Example 2B were performed in the same manner as Comparative Example 2A except for the reaction temperature T.
  • the sulfur content and metal content of the desulfurized heavy oil of Comparative Example 2B were values shown in Table 4 below.
  • the desulfurization ratio of Comparative Example 2B calculated by the same method as that of Example 1A was a value shown in Table 5 below.
  • the metal removal rate of Comparative Example 2B calculated by the same method as that of Example 1 was a value shown in Table 5 below.
  • KS of Comparative Example 2B calculated by the same method as Example 1A was a value shown in Table 5 below.
  • KM of Comparative Example 2B calculated by the same method as Example 1A was a value shown in Table 5 below.
  • FIG. 4 shows that even if the desulfurization rate in the hydrodesulfurization of mixed oil 1 to 3 is substantially equal to the desulfurization rate in the hydrodesulfurization of atmospheric residual oil AR1, AR2, hydrogen of mixed oil 1 to 3
  • the demetallization rate in the chemical desulfurization has been shown to be higher than the demetallization rate in the hydrodesulfurization of atmospheric residual oil AR1, AR2.
  • the correspondence between 1000 / T shown in Table 5 and the reaction rate constant kM of the demetallation reaction is shown in FIG. FIG.
  • Example 1D calculated from the Arrhenius plot are shown in Table 6 below. Based on the above equation 7, the reaction rate constant kM of the demetalization reaction at 370 ° C. (643.15 K) was calculated. The reaction rate constant kM of Example 1D calculated from the above equation 7 is shown in Table 6 below.
  • Example 2D The Arrhenius plot of Example 2D was made based on Examples 2A, 2B and 2C in the same manner as Example 1D. From the Arrhenius plot of Example 2D, the regression line of Example 2D represented by the formula 7 was calculated in the same manner as in Example 1D. Ea and A of Example 2D are shown in Table 6 below. The reaction rate constant kM of the above-mentioned equation 7 to example 2D was calculated by the same method as in example 1D. The reaction rate constant kM of Example 2D is shown in Table 6 below.
  • [POM] at each LHSV of Example 2D was calculated in the same manner as Example 1D.
  • [POM] in each LHSV of Example 2D is shown in Table 6 below.
  • the demetalization rate in each LHSV of Example 2D was calculated in the same manner as in Example 1D.
  • the demetalization rate in each LHSV of Example 2D is shown in Table 6 below.
  • Example 3D The Arrhenius plot of Example 3D was made based on Examples 3A, 3B and 3C in the same manner as Example 1D. From the Arrhenius plot of Example 3D, the regression line of Example 3D represented by the formula 7 was calculated in the same manner as in Example 1D. Ea and A of Example 3D are shown in Table 6 below. The reaction rate constant kM of Example 3D was calculated in the same manner as in Example 1D. The reaction rate constant kM of Example 3D is shown in Table 6 below.
  • [POM] at each LHSV of Example 3D was calculated in the same manner as Example 1D.
  • [POM] in each LHSV of Example 3D is shown in Table 6 below.
  • the demetalization rate at each LHSV of Example 3D was calculated in the same manner as in Example 1D.
  • the demetalation rate in each LHSV of Example 3D is shown in Table 6 below.
  • Comparative Example 1D An Arrhenius plot of Comparative Example 1D was created based on Comparative Examples 1A, 1B and 1C in the same manner as Example 1D. In the same manner as in Example 1D, a regression line of Comparative Example 1D represented by the above-described Formula 7 was calculated from the Arrhenius plot of Comparative Example 1D. Ea and A of Comparative Example 1D are shown in Table 6 below. The reaction rate constant kM of the comparative example 1D was calculated from the above equation 7 in the same manner as in the example 1D. The reaction rate constant kM of Comparative Example 1D is shown in Table 6 below.
  • [POM] at each LHSV of Comparative Example 1D was calculated in the same manner as Example 1D.
  • [POM] in each LHSV of Comparative Example 1D is shown in Table 6 below.
  • the demetalization rate in each LHSV of Comparative Example 1D was calculated in the same manner as in Example 1D.
  • the demetalization rate in each LHSV of Comparative Example 1D is shown in Table 6 below.
  • Comparative Example 2D An Arrhenius plot of Comparative Example 2D was created based on Comparative Examples 2A and 2B in the same manner as Example 1D.
  • the regression line of Comparative Example 2D represented by the above-described Formula 7 was calculated from the Arrhenius plot of Comparative Example 2D in the same manner as in Example 1D.
  • Ea and A of Comparative Example 2D are shown in Table 6 below.
  • the reaction rate constant kM of Comparative Example 2D was calculated from the above Formula 7 in the same manner as in Example 1D.
  • the reaction rate constant kM of Comparative Example 2D is shown in Table 6 below.
  • [POM] at each LHSV of Comparative Example 2D was calculated in the same manner as Example 1D.
  • [POM] in each LHSV of Comparative Example 2D is shown in Table 6 below.
  • the demetalation rate in each LHSV of Comparative Example 2D was calculated in the same manner as in Example 1D.
  • the demetalization rate in each LHSV of Comparative Example 2D is shown in Table 6 below.
  • FIG. 6 shows that, even in hydrodesulfurization under severe reaction conditions in which the liquid hourly space velocity is 0.3 h ⁇ 1 or more, the demetallization rates of Mixed Oils 1 to 3 are sufficiently high.
  • products with relatively high market prices such as gasoline and gas oil can be produced from heavy oils such as normal pressure residual oil and deasphalted oil.

Landscapes

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

Abstract

La présente invention concerne un procédé de production d'une huile hydrocarbonée qui comprend une étape d'obtention d'huile lourde désulfurée par hydrodésulfuration d'une première charge d'alimentation comprenant un résidu atmosphérique, et une étape d'obtention d'un produit par craquage catalytique fluide d'une seconde charge d'alimentation comprenant une huile lourde désulfurée. La vitesse spatiale du liquide dans l'hydrodésulfuration est de 0,3 h-1 à 1,0 h-1. La proportion d'huile désasphaltée dans la première charge d'alimentation est de 30 à 75 % en volume. La teneur en asphaltène dans la première charge d'alimentation est de 0 à 1 % en masse.
PCT/JP2018/035161 2017-11-29 2018-09-21 Procédé de production d'une huile hydrocarbonée WO2019106921A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
JP2017-229026 2017-11-29
JP2017229026A JP2019099611A (ja) 2017-11-29 2017-11-29 炭化水素油の製造方法

Publications (1)

Publication Number Publication Date
WO2019106921A1 true WO2019106921A1 (fr) 2019-06-06

Family

ID=66663902

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/JP2018/035161 WO2019106921A1 (fr) 2017-11-29 2018-09-21 Procédé de production d'une huile hydrocarbonée

Country Status (2)

Country Link
JP (1) JP2019099611A (fr)
WO (1) WO2019106921A1 (fr)

Cited By (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US11230673B1 (en) 2020-09-01 2022-01-25 Saudi Arabian Oil Company Processes for producing petrochemical products that utilize fluid catalytic cracking of a lesser boiling point fraction with steam
US11230672B1 (en) 2020-09-01 2022-01-25 Saudi Arabian Oil Company Processes for producing petrochemical products that utilize fluid catalytic cracking
US11242493B1 (en) 2020-09-01 2022-02-08 Saudi Arabian Oil Company Methods for processing crude oils to form light olefins
WO2022050976A1 (fr) * 2020-09-01 2022-03-10 Saudi Arabian Oil Company Procédés de production de produits pétrochimiques à partir de résidus atmosphériques
US11332680B2 (en) 2020-09-01 2022-05-17 Saudi Arabian Oil Company Processes for producing petrochemical products that utilize fluid catalytic cracking of lesser and greater boiling point fractions with steam
US11352575B2 (en) 2020-09-01 2022-06-07 Saudi Arabian Oil Company Processes for producing petrochemical products that utilize hydrotreating of cycle oil
US11352573B2 (en) 2017-05-31 2022-06-07 Saudi Arabian Oil Company High-severity fluidized catalytic cracking systems and processes having partial catalyst recycle
US11434432B2 (en) 2020-09-01 2022-09-06 Saudi Arabian Oil Company Processes for producing petrochemical products that utilize fluid catalytic cracking of a greater boiling point fraction with steam

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
JPH0711259A (ja) * 1993-06-22 1995-01-13 Idemitsu Kosan Co Ltd 重質油の処理方法
JP2003238970A (ja) * 2001-12-13 2003-08-27 Idemitsu Kosan Co Ltd 低硫黄ガソリン基材の製造方法
WO2016194686A1 (fr) * 2015-05-29 2016-12-08 Ｊｘエネルギー株式会社 Procédé de production d'huile hydrotraitée et procédé de production d'huile de craquage catalytique
JP2017186408A (ja) * 2016-04-01 2017-10-12 Ｊｘｔｇエネルギー株式会社 炭化水素油の製造方法

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
JPH0711259A (ja) * 1993-06-22 1995-01-13 Idemitsu Kosan Co Ltd 重質油の処理方法
JP2003238970A (ja) * 2001-12-13 2003-08-27 Idemitsu Kosan Co Ltd 低硫黄ガソリン基材の製造方法
WO2016194686A1 (fr) * 2015-05-29 2016-12-08 Ｊｘエネルギー株式会社 Procédé de production d'huile hydrotraitée et procédé de production d'huile de craquage catalytique
JP2017186408A (ja) * 2016-04-01 2017-10-12 Ｊｘｔｇエネルギー株式会社 炭化水素油の製造方法

Cited By (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US11352573B2 (en) 2017-05-31 2022-06-07 Saudi Arabian Oil Company High-severity fluidized catalytic cracking systems and processes having partial catalyst recycle
US11230673B1 (en) 2020-09-01 2022-01-25 Saudi Arabian Oil Company Processes for producing petrochemical products that utilize fluid catalytic cracking of a lesser boiling point fraction with steam
US11230672B1 (en) 2020-09-01 2022-01-25 Saudi Arabian Oil Company Processes for producing petrochemical products that utilize fluid catalytic cracking
US11242493B1 (en) 2020-09-01 2022-02-08 Saudi Arabian Oil Company Methods for processing crude oils to form light olefins
WO2022050976A1 (fr) * 2020-09-01 2022-03-10 Saudi Arabian Oil Company Procédés de production de produits pétrochimiques à partir de résidus atmosphériques
US11332680B2 (en) 2020-09-01 2022-05-17 Saudi Arabian Oil Company Processes for producing petrochemical products that utilize fluid catalytic cracking of lesser and greater boiling point fractions with steam
US11352575B2 (en) 2020-09-01 2022-06-07 Saudi Arabian Oil Company Processes for producing petrochemical products that utilize hydrotreating of cycle oil
US11434432B2 (en) 2020-09-01 2022-09-06 Saudi Arabian Oil Company Processes for producing petrochemical products that utilize fluid catalytic cracking of a greater boiling point fraction with steam
US11505754B2 (en) 2020-09-01 2022-11-22 Saudi Arabian Oil Company Processes for producing petrochemical products from atmospheric residues

Also Published As

Publication number Publication date
JP2019099611A (ja) 2019-06-24

Similar Documents

Publication Publication Date Title
WO2019106921A1 (fr) Procédé de production d'une huile hydrocarbonée
AU657567B2 (en) A method of treatment of heavy hydrocarbon oil
KR102447300B1 (ko) 선박용 연료들의 제조를 위한 고정층 수소화 처리, 수소화 처리된 잔사유 분획물의 분리 및 접촉 분해 스텝을 포함하는 전환 프로세스
EP2828358B1 (fr) Traitement par l'hydrogène et craquage catalytique fluide intégré destiné au traitement d'un pétrole brut
US9605218B2 (en) Integrated hydrocracking and slurry hydroconversion of heavy oils
EP2821462B1 (fr) Additifs pour la maximisation d'oléfines légères dans des unités de craquage catalytique fluide et procédé
US20190078027A1 (en) Hydroprocessing of high density cracked fractions
TWI558806B (zh) 在沸騰床反應器系統中處理減壓渣油以及減壓瓦斯油的製程
JP6770953B2 (ja) 水素化処理油の製造方法及び接触分解油の製造方法
JP5460224B2 (ja) 高芳香族炭化水素油の製造方法
JP5406629B2 (ja) 高芳香族炭化水素油の製造方法
KR102444820B1 (ko) 수소화분해 공정을 위해 촉매 적재를 최적화하는 방법
JP5563491B2 (ja) 重質炭化水素油の水素化処理方法
JP6812265B2 (ja) 熱分解重質軽油の処理方法
JP6548223B2 (ja) 燃料油基材の製造方法
Trambouze Engineering of hydrotreating processes
JP6426027B2 (ja) 流動接触分解装置およびその装置を用いた原料油の接触分解方法
JP2017186408A (ja) 炭化水素油の製造方法
JP5314355B2 (ja) 炭化水素油の製造方法
JP6283561B2 (ja) 燃料油基材の製造方法
CN112745953B (zh) 一种加氢处理脱油沥青的方法和系统
JP2003238970A (ja) 低硫黄ガソリン基材の製造方法
JP2023501180A (ja) 脱油アスファルトを水素化処理するための方法およびシステム
US20200199464A1 (en) Naphthenic compositions derived from fcc process fractions
AU2018341697A1 (en) Optimized global positioning system correction message for interoperable train control messaging transport

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 18883702

Country of ref document: EP

Kind code of ref document: A1

NENP Non-entry into the national phase

Ref country code: DE

122 Ep: pct application non-entry in european phase

Ref document number: 18883702

Country of ref document: EP

Kind code of ref document: A1