WO2008010799A1 - Procédé de désulfurisation d'hydrocarbures - Google Patents

Procédé de désulfurisation d'hydrocarbures Download PDF

Info

Publication number
WO2008010799A1
WO2008010799A1 PCT/US2006/027987 US2006027987W WO2008010799A1 WO 2008010799 A1 WO2008010799 A1 WO 2008010799A1 US 2006027987 W US2006027987 W US 2006027987W WO 2008010799 A1 WO2008010799 A1 WO 2008010799A1
Authority
WO
WIPO (PCT)
Prior art keywords
hydrocarbonaceous
boiling
stream
desulfurization
zone
Prior art date
Application number
PCT/US2006/027987
Other languages
English (en)
Inventor
Vasant P. Thakkar
Original Assignee
Uop Llc
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 Uop Llc filed Critical Uop Llc
Priority to RU2009105660/04A priority Critical patent/RU2402594C1/ru
Priority to EP06787821A priority patent/EP2041245A4/fr
Priority to PCT/US2006/027987 priority patent/WO2008010799A1/fr
Priority to CN200680055639.3A priority patent/CN101506334B/zh
Priority to CA2657780A priority patent/CA2657780C/fr
Publication of WO2008010799A1 publication Critical patent/WO2008010799A1/fr

Links

Classifications

    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G65/00—Treatment of hydrocarbon oils by two or more hydrotreatment processes only
    • C10G65/02—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only
    • C10G65/12—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only including cracking steps and other hydrotreatment steps
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • 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
    • C10G2300/1051—Kerosene having a boiling range of about 180 - 230 °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
    • C10G2300/1037—Hydrocarbon fractions
    • C10G2300/1048—Middle distillates
    • C10G2300/1055—Diesel having a boiling range of about 230 - 330 °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
    • C10G2300/20—Characteristics of the feedstock or the products
    • C10G2300/201—Impurities
    • C10G2300/202—Heteroatoms content, i.e. S, N, O, P
    • 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
    • C10G2300/20—Characteristics of the feedstock or the products
    • C10G2300/201—Impurities
    • C10G2300/207—Acid gases, e.g. H2S, COS, SO2, HCN
    • 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
    • C10G2300/20—Characteristics of the feedstock or the products
    • C10G2300/30—Physical properties of feedstocks or products
    • C10G2300/301—Boiling range
    • 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
    • C10G2300/4018—Spatial velocity, e.g. LHSV, WHSV
    • 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
    • C10G2400/00—Products obtained by processes covered by groups C10G9/00 - C10G69/14
    • C10G2400/02—Gasoline
    • 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
    • C10G2400/00—Products obtained by processes covered by groups C10G9/00 - C10G69/14
    • C10G2400/04—Diesel oil

Definitions

  • hydrodesulfurization processes have been used by petroleum refiners to produce more valuable hydrocarbonaceous streams such as naphtha, gasoline, kerosene and diesel, for example, having lower concentrations of sulfur and nitrogen.
  • Feedstocks most often subjected to hydrotreating or desulfurization are normally liquid hydrocarbonaceous streams such as naphtha, kerosene, diesel, gas oil, vacuum gas oil (VGO) and reduced crude, for example.
  • hydrodesulfurization severity is selected to produce an improvement sufficient to produce a marketable product or a suitable feedstock for downstream processing.
  • Desulfurization is generally accomplished by contacting the hydrocarbonaceous feedstock in a desulfurization reaction vessel or zone with a suitable desulfurization catalyst under conditions of elevated temperature and pressure in the presence of hydrogen to yield a product containing the desired maximum limits of sulfur.
  • a suitable desulfurization catalyst under conditions of elevated temperature and pressure in the presence of hydrogen to yield a product containing the desired maximum limits of sulfur.
  • the operating conditions and the desulfurization catalysts within the desulfurization reactor influence the quality of the desulfurized products.
  • US 5,114,562 Bl discloses a process wherein middle distillate petroleum streams are hydrotreated to produce a low sulfur and low aromatic product in two reaction zones in series.
  • the effluent of the first reaction zone is purged of hydrogen sulfide by hydrogen stripping and then reheated by indirect heat exchange.
  • the second reaction zone employs a sulfur-sensitive noble metal hydrogenation catalyst.
  • the present invention is an improved process for the production of low sulfur hydrocarbonaceous products.
  • a first hydrocarbonaceous feedstock comprising hydrocarbon components boiling above 343°C and hydrogen is reacted in a first desulfurization zone to produce a first desulfurization zone effluent which is introduced into a vapor-liquid separator operated at an elevated temperature to provide a vaporous stream comprising lower boiling hydrocarbonaceous compounds and hydrogen and a liquid hydrocarbonaceous stream comprising hydrocarbon components having a reduced concentration of sulfur.
  • the vaporous stream comprising lower boiling hydrocarbonaceous compounds, hydrogen, and a second hydrocarbonaceous feedstock comprising hydrocarbon components boiling below 371 0 C are reacted in a hydrocracking zone to produce a hydrocracking zone effluent which is introduced together with a hydrocarbonaceous recycle stream preferably boiling in the range from 149°C to 371 °C to a hydrogenation zone to produce a hydrogenation zone effluent which is fractionated to produce an ultra low sulfur hydrocarbonaceous stream preferably boiling in the range from 149 0 C to 371 0 C.
  • the liquid hydrocarbonaceous stream provided by the vapor- liquid separator is fractionated to produce a hydrocarbonaceous recycle stream preferably boiling in the range from 149°C to 371°C and a liquid hydrocarbonaceous stream comprising hydrocarbon components boiling above 371 0 C and having a reduced concentration of sulfur.
  • Other embodiments of the present invention encompass further details such as types and descriptions of feedstocks, desulfurization catalysts, hydrocracking catalysts and preferred operating conditions including temperatures and pressures, all of which are hereinafter disclosed in the following discussion of each of these facets of the invention.
  • the drawing is a simplified process flow diagram of a preferred embodiment of the present invention. DETAILED DESCRIPTION OF THE INVENTION
  • the first feedstock which is introduced into the first desulfurization zone preferably contains components boiling above 343°C and more preferably boiling above 371 0 C and includes, for example, atmospheric gas oils, vacuum gas oils, cracked gas oils, coker distillates, straight run distillates, solvent deasphalted oils, pyrolysis-derived oils, high boiling synthetic oils and cat cracker distillates.
  • a preferred feedstock is a gas oil or other fraction having at least 50% by weight and most usually at least 75% by weight of its components boiling at a temperature between 315°C and 538°C.
  • the first feedstock is reacted with hydrogen in a first desulfurization zone containing desulfurization catalyst operated at desulfurization conditions.
  • Preferred desulfurization conditions include a temperature from 204 0 C to 482°C and a liquid hourly space velocity of the hydrocarbonaceous feed from 0.1 hr "1 to 10 hr "1 .
  • Suitable desulfurization catalysts for use in the present invention are any known conventional hydrotreating catalysts and include those which are comprised of at least one Group VIII metal, preferably iron, cobalt and nickel, more preferably cobalt and/or nickel and at least one Group VI metal, preferably molybdenum and tungsten, on a high surface area support material, preferably alumina.
  • Other suitable desulfurization catalysts include zeolitic catalysts, as well as noble metal catalysts where the noble metal is selected from palladium and platinum. It is within the scope of the present invention that more than one type of desulfurization catalyst be used in the same reaction vessel.
  • the Group VIII metal is typically present in an amount ranging from 2 to 20 weight percent, preferably from 4 to 12 weight percent.
  • the Group VI metal will typically be present in an amount ranging from 1 to 25 weight percent, preferably from 2 to 25 weight percent.
  • Typical desulfurization temperatures range from 204 0 C to 482 0 C with pressures from 2.1 MPa to 17.3 MPa, preferably from 2.1 MPa to l3.9 MPa.
  • the resulting effluent from the first desulfurization zone is introduced into a vapor-liquid separator preferably operated at a temperature greater than 288°C to provide a vaporous stream comprising hydrogen, hydrogen sulfide and lower boiling hydrocarbonaceous compounds boiling up to 371 °C and a first liquid hydrocarbonaceous stream comprising hydrocarbon components boiling above 371°C and having a reduced concentration of sulfur.
  • This first liquid hydrocarbonaceous stream also contains a portion of hydrocarbons boiling in the range from 149°C to 371 0 C is preferably introduced into a hot flash zone, then a cold flash zone and subsequently fractionated to provide a hydrocarbonaceous recycle stream containing hydrocarbons boiling in the range from 149°C to 371°C and a second liquid hydrocarbonaceous stream comprising hydrocarbon components boiling above 371 0 C and having a reduced concentration of sulfur.
  • This second liquid hydrocarbonaceous stream is preferably utilized as a suitable feedstock for a fluid catalytic cracking process.
  • the vaporous stream comprising hydrogen, hydrogen sulfide and lower boiling hydrocarbonaceous compounds boiling up to 371 0 C and a second hydrocarbonaceous feedstock comprising hydrocarbon components boiling below 371 0 C is passed to a hydrocracking zone containing hydrocracking catalyst to produce a hydrocracking zone effluent.
  • the second hydrocarbonaceous feedstock may be any suitable feedstock boiling below 371 0 C and preferably boils in the range from 177°C to 371 0 C.
  • suitable feedstocks for example, include straight run middle distillate, kerosene and diesel boiling range hydrocarbons, coker distillate and light cycle oil.
  • the hydrocracking zone may contain one or more beds of the same or different catalyst.
  • the preferred hydrocracking catalysts when the preferred products are middle distillates the preferred hydrocracking catalysts utilize amorphous bases or low-level zeolite bases combined with one or more Group VIII or Group VIB metal hydrogenating components.
  • the hydrocracking zone when the preferred products are in the gasoline boiling range, the hydrocracking zone contains a catalyst which comprises, in general, any crystalline zeolite cracking base upon which is deposited a minor proportion of a Group VIII metal hydrogenating component. Additional hydrogenating components may be selected from Group VIB for incorporation with the zeolite base.
  • the zeolite cracking bases are sometimes referred to in the art as molecular sieves and are usually composed of silica, alumina and one or more exchangeable cations such as sodium, magnesium, calcium, rare earth metals, etc. They are further characterized by crystal pores of relatively uniform diameter between 4 and 14 Angstroms. It is preferred to employ zeolites having a relatively high silica/alumina mole ratio between 3 and 12. Suitable zeolites found in nature include, for example, mordenite, stilbite, heulandite, ferrierite, dachiardite, chabazite, erionite and faujasite.
  • Suitable synthetic zeolites include, for example, the B, X, Y and L crystal types, e.g., synthetic faujasite and mordenite.
  • the preferred zeolites are those having crystal pore diameters between 8-12 Angstroms, wherein the silica/alumina mole ratio is 4 to 6.
  • a prime example of a zeolite falling in the preferred group is synthetic Y molecular sieve.
  • the natural occurring zeolites are normally found in a sodium form, an alkaline earth metal form, or mixed forms.
  • the synthetic zeolites are nearly always prepared first in the sodium form.
  • Hydrogen or "decationized" Y zeolites of this nature are more particularly described in US-A-3, 130,006.
  • Mixed polyvalent metal-hydrogen zeolites may be prepared by ion-exchanging first with an ammonium salt, then partially back exchanging with a polyvalent metal salt and then calcining.
  • the hydrogen forms can be prepared by direct acid treatment of the alkali metal zeolites.
  • the preferred cracking bases are those which are at least 10 percent, and preferably at least 20 percent, metal-cation- deficient, based on the initial ion-exchange capacity.
  • a specifically desirable and stable class of zeolites are those wherein at least 20 percent of the ion exchange capacity is satisfied by hydrogen ions.
  • the active metals employed in the preferred hydrocracking catalysts of the present invention as hydrogenation components are those of Group VIII, i.e., iron, cobalt, nickel, ruthenium, rhodium, palladium, osmium, iridium and platinum.
  • other promoters may also be employed in conjunction therewith, including the metals of Group VIB, e.g., molybdenum and tungsten.
  • the amount of hydrogenating metal in the catalyst can vary within wide ranges. Broadly speaking, any amount between 0.05 percent and 30 percent by weight may be used. In the case of the noble metals, it is normally preferred to use 0.05 to 2 weight percent.
  • the preferred method for incorporating the hydrogenating metal is to contact the zeolite base material with an aqueous solution of a suitable compound of the desired metal wherein the metal is present in a cationic form.
  • the resulting catalyst powder is then filtered, dried, pelleted with added lubricants, binders or the like if desired, and calcined in air at temperatures of, e.g., 371°-648°C in order to activate the catalyst and decompose ammonium ions.
  • the zeolite component may first be pelleted, followed by the addition of the hydrogenating component and activation by calcining.
  • the foregoing catalysts may be employed in undiluted form, or the powdered zeolite catalyst may be mixed and copelleted with other relatively less active catalysts, diluents or binders such as alumina, silica gel, silica-alumina cogels, activated clays and the like in proportions ranging between 5 and 90 weight percent.
  • diluents may be employed as such or they may contain a minor proportion of an added hydrogenating metal such as a Group VIB and/or Group VIII metal.
  • Additional metal promoted hydrocracking catalysts may also be utilized in the process of the present invention which comprises, for example, aluminophosphate molecular sieves, crystalline chromosilicates and other crystalline silicates. Crystalline chromosilicates are more fully described in US-A-4,363,718.
  • the hydrocracking is conducted in the presence of hydrogen and preferably at hydrocracking conditions which include a temperature from (232 0 C) to 468 0 C, a pressure from 3548 IcPa to 20785 kPa, a liquid hourly space velocity (LHSV) from 0.1 to 30 hr '1 , and a hydrogen circulation rate from 337 normal m /m ) to 4200 normal m /m .
  • the hydrocracking zone effluent and a hydrocarbonaceous recycle stream preferably boiling in the range from 232°C to 371 0 C is preferably passed directly into a hydrogenation zone containing hydrogenation catalyst to produce a hydrogenation zone effluent.
  • the hydrogenation catalyst may be selected from any known hydrogenation or desulfurization catalyst. This catalyst may be the same or different from the desulfurization catalyst used in the desulfurization zone and may be selected from known desulfurization catalysts such as those described hereinabove for example. Preferred hydrogenation conditions may be selected from those ranges taught for the desulfurization zone and may be more, less or equal to the severity of reaction conditions selected for the desulfurization zone. [0020] The resulting hydrogenation zone effluent is partially condensed and introduced into a cold vapor-liquid separator operated at a temperature from 21 0 C to 60°C to produce a hydrogen-rich gaseous stream containing hydrogen sulfide and a liquid hydrocarbonaceous stream.
  • the resulting hydrogen-rich gaseous stream is preferably passed through an acid gas scrubbing zone to reduce the concentration of hydrogen sulfide to produce a purified hydrogen-rich gaseous steam, a portion of which may then be recycled as desired or required.
  • the liquid hydrocarbonaceous steam from the cold vapor-liquid separator is preferably introduced into a cold flash drum to remove dissolved hydrogen and normally gaseous hydrocarbons and subsequently sent to a fractionation zone to produce a low sulfur diesel product stream. It is preferred that the diesel product stream contains less than 50 wppm sulfur, more preferably 10 wppm sulfur.
  • the make-up hydrogen may be introduced into the process at any convenient location.
  • a feed stream comprising a heavy vacuum gas oil enters the process through line 1 and is admixed with a hydrogen-rich gaseous stream provided via line 28 and the resulting admixture is introduced via line 2 into desulfurization zone 3.
  • Hydrogen quench is provided to desulfurization zone 3 via lines 30 and 31.
  • a resulting effluent from desulfurization zone 3 is transported via line 4 and introduced into hot vapor-liquid separator 5.
  • a gaseous stream comprising hydrogen, hydrogen sulfide and lower boiling range hydrocarbons is removed from hot vapor-liquid separator 5 via line 17 and is admixed with a light cycle oil carried via line 18 and boiling in the middle distillate range, and the resulting admixture is transported via line 19 and introduced into reactor 20 wherein the stream contacts hydrocracking zone 21.
  • the resulting effluent from hydrocracking zone 21 is passed directly to hydrogenation zone 22 which is contained in reaction zone 20.
  • a resulting effluent from hydrogenation zone 22 is carried via line 23 and introduced into heat-exchanger 24.
  • a resulting cooled and partially condensed stream is removed from heat- exchanger 24 via line 25 and introduced into cold vapor-liquid separator 26.
  • a hydrogen-rich gaseous stream is removed from cold vapor-liquid separator 26 via line 27 and is introduced into desulfurization zone 3 via lines 28, 29, 30 and 31 as hereinabove described.
  • a liquid hydrocarbonaceous stream is removed from cold vapor-liquid separator 26 via line 32 and introduced into cold flash drum 33.
  • a gaseous stream comprising hydrogen and normally gaseous hydrocarbons is removed from cold flash drum 33 via line 34.
  • a liquid stream comprising diesel boiling range hydrocarbons is removed from cold flash drum 33 via line 35 and introduced into fractionation zone 36.
  • An ultra low sulfur diesel stream is recovered from fractionation zone 36 and is removed therefrom via line 38.
  • a hydrocarbonaceous stream comprising compounds boiling below the diesel range is removed from fractionation zone 36 via line 37 and recovered.
  • a liquid stream is removed from hot vapor-liquid separator 5 via line 6 and introduced into hot flash drum 7.
  • a vapor stream comprising hydrogen and lower boiling hydrocarbons is removed from hot flash drum 7 via line 8 and recovered.
  • a liquid hydrocarbonaceous stream containing hydrocarbons boiling at a temperature greater than 371°C and diesel boiling range hydrocarbons is removed from hot flash drum 7 via line 9 and is introduced along with a hereinabove described vapor stream provided via line 34 and the resulting admixture is introduced via line 10 into stripping zone 11.
  • a stream comprising hydrogen, normally gaseous hydrocarbons and gasoline boiling range hydrocarbons is removed from stripping zone 11 via line 12 and recovered.
  • a liquid hydrocarbonaceous stream comprising hydrocarbons boiling at a temperature greater than 371 0 C and diesel boiling range hydrocarbons is removed from stripping zone 11 via line 13 and introduced into fractionation zone 14.
  • a stream comprising lower boiling hydrocarbons is removed from fractionation zone 14 via line 15 and recovered.
  • a liquid hydrocarbonaceous stream comprising hydrocarbons boiling at a temperature greater than 371°C is removed from fractionation zone 14 via line 17 and recovered.
  • a liquid stream comprising diesel boiling range hydrocarbons is removed from fractionation zone 14 via line 16 and is introduced into reaction zone 20 as hereinabove described.

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

L'invention concerne un procédé de production de produits hydrocarbonés à faible teneur en soufre. Les matières premières hydrocarbonées sont traitées dans des zones intégrées de désulfurisation (3), d'hydrocraquage (21) et d'hydrogénation (22) afin d'obtenir un diesel à teneur ultra basse en soufre (38), des produits de naphta à faible teneur en soufre (37) et un distillat lourd à faible teneur en soufre (17).
PCT/US2006/027987 2006-07-19 2006-07-19 Procédé de désulfurisation d'hydrocarbures WO2008010799A1 (fr)

Priority Applications (5)

Application Number Priority Date Filing Date Title
RU2009105660/04A RU2402594C1 (ru) 2006-07-19 2006-07-19 Способ десульфуризации углеводородов
EP06787821A EP2041245A4 (fr) 2006-07-19 2006-07-19 Procédé de désulfurisation d'hydrocarbures
PCT/US2006/027987 WO2008010799A1 (fr) 2006-07-19 2006-07-19 Procédé de désulfurisation d'hydrocarbures
CN200680055639.3A CN101506334B (zh) 2006-07-19 2006-07-19 一种烃脱硫的方法
CA2657780A CA2657780C (fr) 2006-07-19 2006-07-19 Procede de desulfurisation d'hydrocarbures

Applications Claiming Priority (1)

Application Number Priority Date Filing Date Title
PCT/US2006/027987 WO2008010799A1 (fr) 2006-07-19 2006-07-19 Procédé de désulfurisation d'hydrocarbures

Publications (1)

Publication Number Publication Date
WO2008010799A1 true WO2008010799A1 (fr) 2008-01-24

Family

ID=38957048

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US2006/027987 WO2008010799A1 (fr) 2006-07-19 2006-07-19 Procédé de désulfurisation d'hydrocarbures

Country Status (5)

Country Link
EP (1) EP2041245A4 (fr)
CN (1) CN101506334B (fr)
CA (1) CA2657780C (fr)
RU (1) RU2402594C1 (fr)
WO (1) WO2008010799A1 (fr)

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2014011967A1 (fr) * 2012-07-13 2014-01-16 Lyondell Chemical Technology, L.P. Procédé perfectionné de réduction de couleur de diesel à teneur ultra faible en soufre
WO2016093777A1 (fr) * 2014-12-11 2016-06-16 Türkiye Petrol Rafinerileri A. S. Procédé de production de diesel

Families Citing this family (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CA2657780C (fr) * 2006-07-19 2012-02-07 Uop Llc Procede de desulfurisation d'hydrocarbures
KR101897454B1 (ko) * 2011-04-15 2018-09-12 아디트야 비를라 사이언스 앤 테크놀로지 컴퍼니 리미티드 황화나트륨을 분리 및 정제하는 방법
FR2984916B1 (fr) * 2011-12-23 2014-01-17 IFP Energies Nouvelles Procede ameliore de conversion d'une charge lourde en distillat moyen faisant appel a un pretraitement en amont de l'unite de craquage catalytique

Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6296758B1 (en) * 1998-09-29 2001-10-02 Uop Llc Hydrocracking process
US6379533B1 (en) * 2000-12-18 2002-04-30 Uop Llc Hydrocracking process for production of LPG and distillate hydrocarbons

Family Cites Families (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US5447621A (en) * 1994-01-27 1995-09-05 The M. W. Kellogg Company Integrated process for upgrading middle distillate production
US6179995B1 (en) * 1998-03-14 2001-01-30 Chevron U.S.A. Inc. Residuum hydrotreating/hydrocracking with common hydrogen supply
US6444116B1 (en) * 2000-10-10 2002-09-03 Intevep, S.A. Process scheme for sequentially hydrotreating-hydrocracking diesel and vacuum gas oil
CA2657780C (fr) * 2006-07-19 2012-02-07 Uop Llc Procede de desulfurisation d'hydrocarbures

Patent Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6296758B1 (en) * 1998-09-29 2001-10-02 Uop Llc Hydrocracking process
US6379533B1 (en) * 2000-12-18 2002-04-30 Uop Llc Hydrocracking process for production of LPG and distillate hydrocarbons

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
See also references of EP2041245A4 *

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2014011967A1 (fr) * 2012-07-13 2014-01-16 Lyondell Chemical Technology, L.P. Procédé perfectionné de réduction de couleur de diesel à teneur ultra faible en soufre
WO2016093777A1 (fr) * 2014-12-11 2016-06-16 Türkiye Petrol Rafinerileri A. S. Procédé de production de diesel

Also Published As

Publication number Publication date
EP2041245A4 (fr) 2010-08-04
RU2009105660A (ru) 2010-08-27
CA2657780C (fr) 2012-02-07
CA2657780A1 (fr) 2008-01-24
EP2041245A1 (fr) 2009-04-01
CN101506334B (zh) 2012-10-03
RU2402594C1 (ru) 2010-10-27
CN101506334A (zh) 2009-08-12

Similar Documents

Publication Publication Date Title
US7591940B2 (en) Combination hydrocracking process for the production of ultra low sulfur diesel
CA2344953C (fr) Procede d'hydrocraquage ameliore
US5980729A (en) Hydrocracking process
US6379532B1 (en) Hydrocracking process
US6623623B2 (en) Simultaneous hydroprocessing of two feedstocks
US7837860B1 (en) Process for the production of low sulfur diesel and high octane naphtha
CA2326310C (fr) Procede d'hydrocraquage ameliore
US6106694A (en) Hydrocracking process
WO2006062712A2 (fr) Procede de conversion d'hydrocarbures
US7470357B1 (en) Hydrocarbon conversion process
US20080023372A1 (en) Hydrocracking Process
US7094332B1 (en) Integrated process for the production of ultra low sulfur diesel and low sulfur fuel oil
US6638418B1 (en) Dual recycle hydrocracking process
US6379533B1 (en) Hydrocracking process for production of LPG and distillate hydrocarbons
US7097760B1 (en) Hydrocarbon process for the production of ultra low sulfur diesel
US7108779B1 (en) Hydrocarbon desulfurization process
US7842180B1 (en) Hydrocracking process
CA2351196C (fr) Hydrocraquage simultane de deux charges d'alimentation
CA2657780C (fr) Procede de desulfurisation d'hydrocarbures
US6387245B1 (en) Hydrocracking process
CA2423946A1 (fr) Processus d'hydrocraquage
EP1752511B1 (fr) Procédé d'hydrocraquage pour la production de diesel à teneur en soufre ultra-faible
CA2491012C (fr) Procede d'hydrocraquage ameliore
CA2525650C (fr) Methode d'hydrocraquage pour la production de carburant diesel a tres basse teneur en soufre
CA2552275C (fr) Processus integre de production de diesel a tres faible teneur en soufre et de mazout a faible teneur en soufre

Legal Events

Date Code Title Description
WWE Wipo information: entry into national phase

Ref document number: 200680055639.3

Country of ref document: CN

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

Ref document number: 06787821

Country of ref document: EP

Kind code of ref document: A1

ENP Entry into the national phase

Ref document number: 2657780

Country of ref document: CA

WWE Wipo information: entry into national phase

Ref document number: 311/DELNP/2009

Country of ref document: IN

REEP Request for entry into the european phase

Ref document number: 2006787821

Country of ref document: EP

WWE Wipo information: entry into national phase

Ref document number: 2006787821

Country of ref document: EP

NENP Non-entry into the national phase

Ref country code: DE

ENP Entry into the national phase

Ref document number: 2009105660

Country of ref document: RU

Kind code of ref document: A