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WO2003091363A1 - Procede de purification - Google Patents

Procede de purification Download PDF

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Publication number
WO2003091363A1
WO2003091363A1 PCT/GB2003/001456 GB0301456W WO03091363A1 WO 2003091363 A1 WO2003091363 A1 WO 2003091363A1 GB 0301456 W GB0301456 W GB 0301456W WO 03091363 A1 WO03091363 A1 WO 03091363A1
Authority
WO
WIPO (PCT)
Prior art keywords
content
liquid hydrocarbon
hydrocarbon feed
organic sulphur
process according
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Ceased
Application number
PCT/GB2003/001456
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English (en)
Inventor
Andreas Jess
Leonid Datsevich
Nicholas John Gudde
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
BP Oil International Ltd
Original Assignee
BP Oil International Ltd
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 BP Oil International Ltd filed Critical BP Oil International Ltd
Priority to AU2003226529A priority Critical patent/AU2003226529A1/en
Publication of WO2003091363A1 publication Critical patent/WO2003091363A1/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

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Classifications

    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G25/00—Refining of hydrocarbon oils in the absence of hydrogen, with solid sorbents
    • C10G25/003—Specific sorbent material, not covered by C10G25/02 or C10G25/03
    • 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
    • C10G2400/06—Gasoil
    • 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
    • C10G2400/08—Jet fuel

Definitions

  • This invention relates to a purification process, in particular one to remove sulphur compounds from hydrocarbon fuels.
  • the present invention provides a process for reducing the sulphur content of a liquid hydrocarbon feed comprising organic sulphur species wherein said process comprises a) contacting the liquid hydrocarbon feed comprising organic sulphur species with a hydrogen containing gas stream to produce a liquid hydrocarbon feed comprising organic sulphur species and an increased hydrogen content b) contacting the liquid hydrocarbon feed comprising organic sulphur species and an increased hydrogen content with a catalyst at elevated temperature and presurre in a reaction zone to generate a liquid hydrocarbon feed with a decreased organic sulphur species content and an increased hydrogen sulphide content c) passing the liquid hydrocarbon feed with a decreased organic sulphur species content and an increased hydrogen sulphide content to a hydrogen sulphide removal zone to produce a liquid hydrocarbon feed with a decreased organic sulphur species content and decreased hydrogen sulphide content.
  • the liquid hydrocarbon feed comprising organic sulphur species is usually a liquid at a temperature of 25°C and at a pressure of lbarg and is generally directly or indirectly derived from a crude oil distillation.
  • the liquid hydrocarbon feed usually contains saturated hydrocarbons e.g. branched and unbranched alkanes and alicyclic hydrocarbons as well as variable amounts of aromatics and/or unsaturated compounds such as olefins.
  • the liquid hydrocarbon feed comprising organic sulphur species may be a middle distillate which may be one or more petroleum fractions with a boiling range of 150- 450°C, preferably 190-390°C.
  • the middle distillate stream is a combination of said petroleum fractions.
  • suitable petroleum fractions include light gas oils (LGO), heavy gas oils (HGO), light cycle oils (LCO), coker gas oils (CGO) and Visbroken gas oils (VBGO).
  • LGO light gas oils
  • HGO heavy gas oils
  • LCO light cycle oils
  • CGO coker gas oils
  • VBGO Visbroken gas oils
  • the liquid hydrocarbon feed comprising organic sulphur species is diesel, gasoline, kerosene or jet fuel and is advantageously diesel or jet fuel.
  • the organic sulphur species usually comprise mercaptans, sulphides, thiophenes, benzothiophenes and dibenzothiophenenes (DBTs), especially hindered alkyl substituted dibenzothiophenes.
  • the liquid hydrocarbon feed comprising organic sulphur species usually has a total sulphur content (expressed as elemental S) of 1000-50000ppm S, preferably 5000-20000p ⁇ m S e.g. 15000ppm S, a DBT content of 100-20000ppm S, preferably 1000-5000ppm S e.g. 3000ppm S, and a hindered-DBT content of 50-
  • the liquid hydrocarbon comprising organic sulphur species is diesel the diesel may contain contaminant sulphur in the range of 10-lOOppm (expressed as elemental S).
  • the liquid hydrocarbon feed comprising organic sulphur species is contacted with the hydrogen containing gas stream to produce a liquid hydrocarbon feed comprising organic sulphur species and an increased hydrogen content.
  • the hydrogen containing gas stream may be provided by a reformer off gas stream but is preferably substantially pure hydrogen.
  • the liquid hydrocarbon comprising organic sulphur species is typically saturated with gaseous hydrogen in a saturator vessel wherein hydrogen is passed through the body of the liquid.
  • the liquid hydrocarbon comprising organic sulphur species is typically saturated with gaseous hydrogen at a temperature of between 250°C-500°C, e.g. 300-400°C e.g. 340°C or 380°C, and at pressure of between 1-100 bar, preferably between 10-60bar e.g. 20-40 bar.
  • the liquid hydrocarbon comprising organic sulphur species usually contains 1-100, preferably 10-90 and especially 20-60 Nm 3 of hydrogen per m 3 .
  • the liquid hydrocarbon feed comprising organic sulphur species may be saturated with hydrogen at location remote from the reaction zone.
  • the liquid hydrocarbon feed comprising organic sulphur species may be saturated with hydrogen immediately upstream of the reaction zone.
  • the liquid hydrocarbon feed comprising organic sulphur species and an increased hydrogen content is then contacted with a catalyst at elevated temperature and presurre in a reaction zone to generate a liquid hydrocarbon feed with a decreased organic sulphur species content and an increased hydrogen sulphide content.
  • Any suitable catalyst may be used in the reaction zone.
  • a catalyst may comprise one or more active components which are dispersed on a catalyst support.
  • active components include, molybdenum, tungsten, platinum, palladium, ruthenium, nickel, cobalt, iron, copper, cerium or rhenium.
  • the catalyst comprises at least two metals selected from the above group and most preferably the catalyst comprises molybdenum or tungsten and at least one additional metal selected from nickel and cobalt.
  • the active component or components may be supported on any suitable catalyst support, such as silica, alumina, silica-alumina, carbon, titania, activated carbon or an alumino-silicate such as a zeolite.
  • the support may be pretreated to incorporate a promoter such as phosphorus or fluorine.
  • the catalyst support may be mixed with a binder such as alumina or silica.
  • the total weight of metal may be between 0.1-70% by weight (as metal) based on the weight of support, preferably between 0.2-20% by weight (as metal) based on the weight of support.
  • the metal(s) may be introduced to the support by any of the well known techniques employed in catalyst preparation e.g. impregnation wherein the pores of the support are filled at least partly with an impregnating solution comprising a soluble precursor salt of the desired metal and the impregnated resulting support material is subsequently dried, optionally calcined and sulphided.
  • the impregnating solution is usually an aqueous solution of a metal nitrate, oxalate, formate, propionate, acetate, chloride, carbonate, or bicarbonate in particular a metal nitrate, chloride or carbonate.
  • the impregnating solution may comprise a metal compound dissolved in an organic solvent e.g. an organometallic compound such as a metal acetylacetonates, metal naphthenates or metal carbonyls.
  • the second metal may also be introduced to the support as described above before or after the incorporation of the initial metal or the incorporation of the additional metal may be simultaneous with the incorporation of the initial metal.
  • the impregnating solutions are usually ammonium paramolybdate and cobalt or nickel nitrate and when a catalyst comprising tungsten and at least one additional metal selected from nickel and cobalt is being prepared the impregnating solutions are usually ammonium paratungstate and cobalt or nickel nitrate.
  • the catalyst usually comprises at least 1% by weight of molybdenum or tungsten (based on the weight of support), usually between 1 -50% by weight of molybdenum or tungsten and preferably between 20-30% by weight of molybdenum or tungsten and at least 0.1% by weight of nickel and/or cobalt (based on the weight of support), usually between 0.1-20% by weight of nickel and/or cobalt and preferably between 3-10% by weight of nickel and/or cobalt.
  • the post treatment usually involves calcination in air, nitrogen or helium at a temperature within the range of 200-800°C, preferably 300-700°C e.g. 350-500°C.
  • the catalyst is advantageously sulphided using a sulphiding agent such as hydrogen sulphide or dimethyl disulphide.
  • a sulphiding agent such as hydrogen sulphide or dimethyl disulphide.
  • the catalyst is usually sulphided at a temperature within the range of 100-400°C, preferably within the range of 250-350°C.
  • the catalyst Prior to contacting the liquid hydrocarbon feed comprising organic sulphur species and an increased hydrogen content with the catalyst the catalyst is usually pretreated.
  • the pretreatment usually involves calcination in air, nitrogen or helium at a temperature within the range of 200-800°C preferably 300-700°C e.g. 350-500°C.
  • the catalyst is reduced at a temperature within the range of 100-800°C preferably 200-700°C with a flowing gas such as hydrogen, carbon monoxide or a light hydrocarbon e.g. C ⁇ -C 4 hydrocarbon.
  • the catalyst is sulphided using a sulphiding agent such as hydrogen sulphide or dimethyl, disulphide.
  • the catalyst is usually sulphided at a temperature within the range of 100-400°C, preferably within the range of 250-350°C.
  • the liquid hydrocarbon feed comprising organic sulphur species and an increased hydrogen content is preferably contacted with the catalyst at a temperature of between 250°C-500°C, e.g. 300-400°C e.g. 340°C or 380°C, and at pressure of between 1-100 bar, preferably between 10-60bar e.g. 20-40 bar.
  • the reaction zone usually comprises a fixed bed catalyst contained within a vessel.
  • the vessel may be one capable of withstanding temperatures of up to 500°C and pressures of up to 100 bar, e.g. a steel pressure vessel.
  • the reaction zone generates a liquid hydrocarbon feed with a decreased organic sulphur species content and an increased hydrogen sulphide content and this is advantageously passed directly (i.e. in the absence of any recycle to the reaction zone) to the hydrogen sulphide removal zone to generate a liquid hydrocarbon feed with a decreased organic sulphur species content and a decreased hydrogen sulphide content.
  • the hydrogen sulphide removal zone may comprise a zone that is maintained at a lower pressure than that of the reaction zone. Consequently the hydrogen sulphide and hydrogen present in the liquid hydrocarbon feed exiting the reaction zone is vapourised in the removal zone and removed from the liquid hydrocarbon product.
  • a gaseous stream may be passed through the hydrogen sulphide removal zone to facilitate the removal of the hydrogen sulphide.
  • the gaseous stream may be comprise an inert gas e.g. nitrogen but is preferably hydrogen.
  • the gas exiting the hydrogen sulphide removal zone may then be advantageously employed to in step (a) of the present invention.
  • the hydrogen sulphide removal zone comprises an adsorbent in an adsorption zone wherein the process comprises contacting the liquid hydrocarbon feed with a decreased organic sulphur species content and an increased hydrogen sulphide content with an adsorbent in an adsorption zone to produce a liquid hydrocarbon feed with a decreased organic sulphur species content and decreased hydrogen sulphide content and an adsorbent with an increased sulphur content.
  • Suitable adsorbents may be provided by porous oxides e.g. metal or non metal oxides.
  • the metal oxides are advantageously di, tri and tetravalent metals, which may be transition or non transition metals or rare earth metals, such as zinc oxide, alumina, titania, cobaltic oxide, zirconia, ceria, molybdenum oxide, magnesia and tungsten oxide.
  • An example of a non metal oxide is silica. More than one type of adsorbent may be present.
  • the adsorbent is selected from zinc oxide, alumina and magnesia or any combinations thereof.
  • the adsorbent may comprise incorporated elemental metal usually selected from the metal Groups VTJIA, IB, D ⁇ , IHB, IVB and NB in particular group NmA e.g. nickel, cobalt and especially the platinum metals e.g. platinum, palladium, ruthenium, rhodium, osmium, and iridium.
  • group NmA e.g. nickel, cobalt and especially the platinum metals e.g. platinum, palladium, ruthenium, rhodium, osmium, and iridium.
  • the groups are as described in the Periodic Table in Basic Inorganic Chemistry by F.A.Cotton, G.Wilkinson and P.L Gaus Publ. John Wiley & Sons, Inc. New York 2nd Ed. 1986.
  • the adsorbent comprises nickel with one or more platinum group metals e.g. platinum.
  • the adsorbent may comprise a zeolite.
  • zeolites may be synthetic e.g. zeolites A, X, Y and L or naturally occurring zeolites e.g. faujasite.
  • the zeolite may also comprise a group NIHA metal as elemental metal, in particular palladium or platinum.
  • the adsorbent may be carbon based e.g. activated carbon.
  • the liquid hydrocarbon feed with a decreased organic sulphur species content and an increased hydrogen sulphide is preferably contacted with the adsorbent at a temperature of between 50°C-200°C, advantageously between 100-150°C e.g. 120°C or 140°C, and at pressure of between 1-50 bar, preferably between 2-20bar e.g. 10-15 bar.
  • the adsorption zone usually comprises a fixed bed of adsorbent contained within a vessel.
  • the vessel may be one capable of withstanding temperatures of up to 500°C and pressures of up to 100 bar, e.g. a steel pressure vessel.
  • the adsorbent of increased sulphur content is preferably stripped of its sulphur content by contact with a stripping gas e.g.
  • the sulphur containing adsorbent is usually contacted with the stripping gas at a temperature elevated above the temperature of adso ⁇ tion.
  • the stripping gas is contacted with the adsorbent at temperatures in the range of 100-6 ⁇ 0°C e.g. 150- 350°C and at a pressure of between 1-100 bar.
  • the hydrogen sulphide removal zone may comprise an amine or a caustic solution wherein the process comprises passing the liquid hydrocarbon feed with a decreased organic sulphur species content and an increased hydrogen sulphide content through a vessel containing an amine or a caustic solution e.g. potassium hydroxide solution or sodium hydroxide solution to produce a liquid hydrocarbon feed with a decreased organic sulphur species content and a decreased hydrogen sulphide content.
  • the liquid hydrocarbon feed with a decreased organic sulphur species content and decreased hydrogen sulphide content usually contains a total amount of the sulphur containing compounds of less than 500ppmS e.g. 200-400ppmS, preferably less than 200ppmS e.g.
  • Fig. 1 shows a reservoir (1) containing a liquid hydrocarbon feed comprising organic sulphur species.
  • the liquid hydrocarbon feed comprising organic sulphur species is passed to a hydrogen saturator (2) via a liquid feed pump (3) wherein it is contacted with gaseous hydrogen which is passed to the hydrogen saturator (2) via line (4) and exits the hydrogen saturator (2) via vent (5).
  • a liquid hydrocarbon feed comprising organic sulphur species and an increased hydrogen content exits the hydrogen saturator via line (6) and is passed into a reaction zone (7) which contains a fixed bed of hydrodesuphurisation catalyst.
  • a liquid hydrocarbon feed with a decreased organic sulphur species content and an increased hydrogen sulphide content exits the reaction zone (7) and is passed via line (8) to an adso ⁇ tion zone (9) which contains a fixed bed of adsorbent.
  • a liquid hydrocarbon feed with a decreased organic sulphur species content and a decreased hydrogen sulphide content exits the adso ⁇ tion zone (9) via line (10).
  • Example 1 The invention is illustrated in the following example.
  • Example 1 The invention is illustrated in the following example.
  • a test rig comprising a liquid feed reservoir, a liquid feed pump, a hydrogen supply, a saturator vessel and a reactor contained within an oven for temperature control was employed.
  • the reactor comprised a steel tube with an internal diameter of 4mm and a length of 1.3m and contained a fixed bed of a presulphided cobalt-mo lydenum on alumina hydrotreating catalyst.
  • the reactor temperature was varied between 360°C- 400°C and the pressure was varied between of 30-70barg.
  • a gas oil containing 260ppm of total sulphur (expressed as elemental S) was passed to the hydrogen saturator wherein it was saturated with gaseous hydrogen and then subsequently passed to the reactor with a Liquid Hourly Space Velocity LHSN of between 1.0-1.4h ' '.
  • the gas oil exiting the reactor was passed to hydrogen sulphide removal zone wherein the hydrogen sulphide was removed
  • Example 2 Example 1 was repeated. The reactor temperature was maintained at 360°C and the pressure was varied between of 10-30barg.
  • a gas oil containing 32ppm of total sulphur (expressed as elemental S) was passed to the hydrogen saturator wherein it was saturated with gaseous hydrogen and then subsequently passed to the reactor with a Liquid Hourly Space Velocity LHSV of between 1-45 h "1 .
  • the gas oil exiting the reactor was passed to hydrogen sulphide removal zone wherein the hydrogen sulphide was removed
  • Example 2 illustrates that a product with less than lOppm can be produced from a gas oil that has been already pretreated.
  • Example 3 The catalyst was replaced with a fixed bed of a US-Y zeolite containing 42% by weight of Al 2 O 3 and 2.7% by weight of Re 2 O 3 .
  • the zeolite was pretreated with nitrogen at 200°C for 1 hour.
  • the reactor temperature was varied between 300-360°C and the pressure was varied between of 10-30barg.
  • a gas oil containing 32ppm of total sulphur (expressed as elemental S) was passed to the hydrogen saturator wherein it was saturated with gaseous hydrogen and then subsequently passed to the reactor with a Liquid Hourly Space Velocity LHSV of between 7-35 h "1 .
  • the gas oil exiting the reactor was passed to hydrogen sulphide removal zone wherein the hydrogen sulphide was removed
  • the US-Y zeolite was replaced with a copper-cerium on zeolite catalyst.
  • the reactor temperature was varied between 300-360°C and the pressure was maintained at 50barg.
  • a gas oil containing 32ppm of total sulphur (expressed as elemental S) was passed to the hydrogen saturator wherein it was saturated with gaseous hydrogen and then subsequently passed to the reactor with a Liquid Hourly Space Velocity LHSV of between 6.9-7.3 h "1 .
  • the gas oil exiting the reactor was passed to hydrogen sulphide removal zone wherein the hydrogen sulphide was removed

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

Abstract

La présente invention a trait à un procédé permettant de réduire la teneur en soufre d'une charge d'hydrocarbures liquides comprenant une espèce sulfureuse organique. Ledit procédé consiste : a) à mettre la charge d'hydrocarbures liquides comprenant une espèce sulfureuse organique en contact avec un flux gazeux contenant de l'hydrogène, de façon à produire une charge d'hydrocarbures liquides comprenant une espèce sulfureuse organique et une teneur en hydrogène augmentée ; b) à mettre la charge d'hydrocarbures liquides comprenant une espèce sulfureuse organique et une teneur en hydrogène augmentée en contact avec un catalyseur, à une température et à une pression élevées, dans une zone de réaction, de façon à générer une charge d'hydrocarbures liquides présentant une teneur en espèce sulfureuse organique réduite et une teneur en sulfure d'hydrogène augmentée ; c) à faire passer la charge d'hydrocarbures liquides présentant une teneur en espèce sulfureuse organique réduite et une teneur en sulfure d'hydrogène augmentée dans une zone d'élimination de sulfure d'hydrogène, de façon à produire une charge d'hydrocarbures liquides présentant une teneur en espèce sulfureuse organique réduite et une teneur en sulfure d'hydrogène réduite.
PCT/GB2003/001456 2002-04-23 2003-04-03 Procede de purification Ceased WO2003091363A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
AU2003226529A AU2003226529A1 (en) 2002-04-23 2003-04-03 Purification process

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GB0209222.9 2002-04-23
GB0209222A GB0209222D0 (en) 2002-04-23 2002-04-23 Purification process

Publications (1)

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WO2003091363A1 true WO2003091363A1 (fr) 2003-11-06

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AU (1) AU2003226529A1 (fr)
GB (1) GB0209222D0 (fr)
TW (1) TW200402467A (fr)
WO (1) WO2003091363A1 (fr)

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WO2005061669A2 (fr) 2003-12-19 2005-07-07 Shell Internationale Research Maatschappij B.V. Systemes, procedes, et catalyseurs pour la production d'un produit brut
DE102006060950A1 (de) 2006-12-20 2008-07-03 Forschungszentrum Jülich GmbH Verfahren zur Reinigung von Mineralölfraktionen sowie zur Durchführung des Verfahrens geeignete Vorrichtung
DE102007046126A1 (de) 2007-09-27 2009-04-09 Forschungszentrum Jülich GmbH Verfahren zur Reinigung von Mineralölfraktionen sowie zur Durchführung des Verfahrens geeignete Vorrichtung
US7534342B2 (en) 2003-12-19 2009-05-19 Shell Oil Company Systems, methods, and catalysts for producing a crude product
WO2009135459A3 (fr) * 2008-05-09 2010-02-18 Forschungszentrum Jülich GmbH Procédé de réduction de la teneur en soufre d'un carburant liquide soufré pour l'utilisation dans un dispositif électrogène et dispositif de mise en oeuvre du procédé
US7678264B2 (en) 2005-04-11 2010-03-16 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US7745369B2 (en) 2003-12-19 2010-06-29 Shell Oil Company Method and catalyst for producing a crude product with minimal hydrogen uptake
US7749374B2 (en) 2006-10-06 2010-07-06 Shell Oil Company Methods for producing a crude product
US7918992B2 (en) 2005-04-11 2011-04-05 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US8377288B2 (en) 2009-09-22 2013-02-19 Bp Corporation North America Inc. Methods and units for mitigation of carbon oxides during hydrotreating
WO2015119767A1 (fr) 2014-02-10 2015-08-13 Archer Daniels Midland Company Procédés améliorés de mélange multi-phase faible
US9393538B2 (en) 2014-10-10 2016-07-19 Uop Llc Process and apparatus for selectively hydrogenating naphtha
US9822317B2 (en) 2014-10-10 2017-11-21 Uop Llc Process and apparatus for selectively hydrogenating naphtha

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US7745369B2 (en) 2003-12-19 2010-06-29 Shell Oil Company Method and catalyst for producing a crude product with minimal hydrogen uptake
US8241489B2 (en) 2003-12-19 2012-08-14 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US8764972B2 (en) 2003-12-19 2014-07-01 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US8506794B2 (en) 2003-12-19 2013-08-13 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US7534342B2 (en) 2003-12-19 2009-05-19 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US8025794B2 (en) 2003-12-19 2011-09-27 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US7588681B2 (en) 2003-12-19 2009-09-15 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US7591941B2 (en) 2003-12-19 2009-09-22 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US7615196B2 (en) 2003-12-19 2009-11-10 Shell Oil Company Systems for producing a crude product
US7674370B2 (en) 2003-12-19 2010-03-09 Shell Oil Company Systems, methods, and catalysts for producing a crude product
WO2005061669A3 (fr) * 2003-12-19 2006-01-05 Shell Oil Co Systemes, procedes, et catalyseurs pour la production d'un produit brut
US7648625B2 (en) 2003-12-19 2010-01-19 Shell Oil Company Systems, methods, and catalysts for producing a crude product
US7628908B2 (en) 2003-12-19 2009-12-08 Shell Oil Company Systems, methods, and catalysts for producing a crude product
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