WO2002083303A1 - Procede de traitement d'un catalyseur et utilisation du catalyseur traite pour l'hydrogenation selective de composes a teneur en soufre - Google Patents
Procede de traitement d'un catalyseur et utilisation du catalyseur traite pour l'hydrogenation selective de composes a teneur en soufre Download PDFInfo
- Publication number
- WO2002083303A1 WO2002083303A1 PCT/US2002/012119 US0212119W WO02083303A1 WO 2002083303 A1 WO2002083303 A1 WO 2002083303A1 US 0212119 W US0212119 W US 0212119W WO 02083303 A1 WO02083303 A1 WO 02083303A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- catalyst
- sulfiding
- silica
- temperature
- hydrogenation
- Prior art date
Links
- 239000003054 catalyst Substances 0.000 title claims abstract description 145
- 238000005984 hydrogenation reaction Methods 0.000 title claims abstract description 75
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 title claims abstract description 46
- 229910052717 sulfur Inorganic materials 0.000 title claims abstract description 46
- 239000011593 sulfur Substances 0.000 title claims abstract description 46
- 150000001875 compounds Chemical class 0.000 title claims abstract description 36
- 238000000034 method Methods 0.000 title claims description 67
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 claims abstract description 35
- 229910000510 noble metal Inorganic materials 0.000 claims abstract description 28
- 230000000694 effects Effects 0.000 claims abstract description 27
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 claims abstract description 26
- 239000001257 hydrogen Substances 0.000 claims abstract description 26
- 229910052739 hydrogen Inorganic materials 0.000 claims abstract description 26
- 239000003795 chemical substances by application Substances 0.000 claims abstract description 21
- 239000000377 silicon dioxide Substances 0.000 claims abstract description 16
- 150000002430 hydrocarbons Chemical class 0.000 claims abstract description 11
- 229930195733 hydrocarbon Natural products 0.000 claims abstract description 10
- 239000004215 Carbon black (E152) Substances 0.000 claims abstract description 7
- 230000002378 acidificating effect Effects 0.000 claims abstract description 7
- 239000011959 amorphous silica alumina Substances 0.000 claims abstract description 7
- YTPLMLYBLZKORZ-UHFFFAOYSA-N Thiophene Chemical compound C=1C=CSC=1 YTPLMLYBLZKORZ-UHFFFAOYSA-N 0.000 claims description 38
- 230000008569 process Effects 0.000 claims description 30
- PNEYBMLMFCGWSK-UHFFFAOYSA-N aluminium oxide Inorganic materials [O-2].[O-2].[O-2].[Al+3].[Al+3] PNEYBMLMFCGWSK-UHFFFAOYSA-N 0.000 claims description 26
- KDLHZDBZIXYQEI-UHFFFAOYSA-N Palladium Chemical compound [Pd] KDLHZDBZIXYQEI-UHFFFAOYSA-N 0.000 claims description 25
- BASFCYQUMIYNBI-UHFFFAOYSA-N platinum Chemical compound [Pt] BASFCYQUMIYNBI-UHFFFAOYSA-N 0.000 claims description 25
- 229930192474 thiophene Natural products 0.000 claims description 19
- IMNFDUFMRHMDMM-UHFFFAOYSA-N N-Heptane Chemical compound CCCCCCC IMNFDUFMRHMDMM-UHFFFAOYSA-N 0.000 claims description 16
- YXFVVABEGXRONW-UHFFFAOYSA-N Toluene Chemical compound CC1=CC=CC=C1 YXFVVABEGXRONW-UHFFFAOYSA-N 0.000 claims description 15
- WQOXQRCZOLPYPM-UHFFFAOYSA-N dimethyl disulfide Chemical group CSSC WQOXQRCZOLPYPM-UHFFFAOYSA-N 0.000 claims description 12
- 229910052763 palladium Inorganic materials 0.000 claims description 12
- 229910052697 platinum Inorganic materials 0.000 claims description 12
- 150000001336 alkenes Chemical class 0.000 claims description 10
- 229920001021 polysulfide Polymers 0.000 claims description 10
- 239000005077 polysulfide Substances 0.000 claims description 10
- 150000008117 polysulfides Polymers 0.000 claims description 10
- UHOVQNZJYSORNB-UHFFFAOYSA-N Benzene Chemical compound C1=CC=CC=C1 UHOVQNZJYSORNB-UHFFFAOYSA-N 0.000 claims description 9
- QMMFVYPAHWMCMS-UHFFFAOYSA-N Dimethyl sulfide Chemical group CSC QMMFVYPAHWMCMS-UHFFFAOYSA-N 0.000 claims description 9
- 239000000203 mixture Substances 0.000 claims description 9
- VLKZOEOYAKHREP-UHFFFAOYSA-N n-Hexane Chemical compound CCCCCC VLKZOEOYAKHREP-UHFFFAOYSA-N 0.000 claims description 9
- TVMXDCGIABBOFY-UHFFFAOYSA-N octane Chemical compound CCCCCCCC TVMXDCGIABBOFY-UHFFFAOYSA-N 0.000 claims description 8
- 239000002904 solvent Substances 0.000 claims description 7
- LSDPWZHWYPCBBB-UHFFFAOYSA-N Methanethiol Chemical group SC LSDPWZHWYPCBBB-UHFFFAOYSA-N 0.000 claims description 6
- WQAQPCDUOCURKW-UHFFFAOYSA-N butanethiol Chemical group CCCCS WQAQPCDUOCURKW-UHFFFAOYSA-N 0.000 claims description 6
- DNJIEGIFACGWOD-UHFFFAOYSA-N ethanethiol Chemical group CCS DNJIEGIFACGWOD-UHFFFAOYSA-N 0.000 claims description 6
- -1 naphthenic groups Chemical group 0.000 claims description 6
- BKIMMITUMNQMOS-UHFFFAOYSA-N nonane Chemical compound CCCCCCCCC BKIMMITUMNQMOS-UHFFFAOYSA-N 0.000 claims description 6
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical group S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 claims description 5
- JRZJOMJEPLMPRA-UHFFFAOYSA-N olefin Natural products CCCCCCCC=C JRZJOMJEPLMPRA-UHFFFAOYSA-N 0.000 claims description 5
- 229910000037 hydrogen sulfide Inorganic materials 0.000 claims description 4
- 229910052750 molybdenum Inorganic materials 0.000 claims description 4
- 125000000962 organic group Chemical group 0.000 claims description 4
- CTQNGGLPUBDAKN-UHFFFAOYSA-N O-Xylene Chemical compound CC1=CC=CC=C1C CTQNGGLPUBDAKN-UHFFFAOYSA-N 0.000 claims description 3
- KJTLSVCANCCWHF-UHFFFAOYSA-N Ruthenium Chemical compound [Ru] KJTLSVCANCCWHF-UHFFFAOYSA-N 0.000 claims description 3
- 125000003118 aryl group Chemical group 0.000 claims description 3
- QGJOPFRUJISHPQ-NJFSPNSNSA-N carbon disulfide-14c Chemical compound S=[14C]=S QGJOPFRUJISHPQ-NJFSPNSNSA-N 0.000 claims description 3
- 229910052804 chromium Inorganic materials 0.000 claims description 3
- 229910052802 copper Inorganic materials 0.000 claims description 3
- 229910052737 gold Inorganic materials 0.000 claims description 3
- 229910052741 iridium Inorganic materials 0.000 claims description 3
- GKOZUEZYRPOHIO-UHFFFAOYSA-N iridium atom Chemical compound [Ir] GKOZUEZYRPOHIO-UHFFFAOYSA-N 0.000 claims description 3
- XEEYBQQBJWHFJM-UHFFFAOYSA-N iron Substances [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 claims description 3
- 229910052742 iron Inorganic materials 0.000 claims description 3
- 229910052748 manganese Inorganic materials 0.000 claims description 3
- 229910052762 osmium Inorganic materials 0.000 claims description 3
- SYQBFIAQOQZEGI-UHFFFAOYSA-N osmium atom Chemical compound [Os] SYQBFIAQOQZEGI-UHFFFAOYSA-N 0.000 claims description 3
- 229910052698 phosphorus Inorganic materials 0.000 claims description 3
- 229910052702 rhenium Inorganic materials 0.000 claims description 3
- 229910052703 rhodium Inorganic materials 0.000 claims description 3
- 239000010948 rhodium Substances 0.000 claims description 3
- MHOVAHRLVXNVSD-UHFFFAOYSA-N rhodium atom Chemical compound [Rh] MHOVAHRLVXNVSD-UHFFFAOYSA-N 0.000 claims description 3
- 229910052707 ruthenium Inorganic materials 0.000 claims description 3
- 229910052709 silver Inorganic materials 0.000 claims description 3
- 229910052718 tin Inorganic materials 0.000 claims description 3
- 229910052721 tungsten Inorganic materials 0.000 claims description 3
- 239000008096 xylene Substances 0.000 claims description 3
- 229910052725 zinc Inorganic materials 0.000 claims description 3
- 125000002877 alkyl aryl group Chemical group 0.000 claims description 2
- 125000000217 alkyl group Chemical group 0.000 claims description 2
- 125000004432 carbon atom Chemical group C* 0.000 claims description 2
- 229910052713 technetium Inorganic materials 0.000 claims 2
- 238000009835 boiling Methods 0.000 description 24
- 239000000047 product Substances 0.000 description 16
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 10
- 238000006243 chemical reaction Methods 0.000 description 9
- 229910002651 NO3 Inorganic materials 0.000 description 6
- NHNBFGGVMKEFGY-UHFFFAOYSA-N Nitrate Chemical compound [O-][N+]([O-])=O NHNBFGGVMKEFGY-UHFFFAOYSA-N 0.000 description 6
- JUJWROOIHBZHMG-UHFFFAOYSA-N Pyridine Chemical compound C1=CC=NC=C1 JUJWROOIHBZHMG-UHFFFAOYSA-N 0.000 description 6
- 239000002245 particle Substances 0.000 description 6
- 229910052757 nitrogen Inorganic materials 0.000 description 5
- 238000004231 fluid catalytic cracking Methods 0.000 description 4
- 238000004817 gas chromatography Methods 0.000 description 4
- 229910052751 metal Inorganic materials 0.000 description 4
- 239000002184 metal Substances 0.000 description 4
- 150000003464 sulfur compounds Chemical class 0.000 description 4
- 230000003197 catalytic effect Effects 0.000 description 3
- 238000006477 desulfuration reaction Methods 0.000 description 3
- 230000023556 desulfurization Effects 0.000 description 3
- 238000004821 distillation Methods 0.000 description 3
- 239000007788 liquid Substances 0.000 description 3
- 239000008188 pellet Substances 0.000 description 3
- 239000000843 powder Substances 0.000 description 3
- 238000012545 processing Methods 0.000 description 3
- UMJSCPRVCHMLSP-UHFFFAOYSA-N pyridine Natural products COC1=CC=CN=C1 UMJSCPRVCHMLSP-UHFFFAOYSA-N 0.000 description 3
- 230000009467 reduction Effects 0.000 description 3
- 229920006395 saturated elastomer Polymers 0.000 description 3
- 241000640882 Condea Species 0.000 description 2
- UQSXHKLRYXJYBZ-UHFFFAOYSA-N Iron oxide Chemical compound [Fe]=O UQSXHKLRYXJYBZ-UHFFFAOYSA-N 0.000 description 2
- 230000033228 biological regulation Effects 0.000 description 2
- 238000004523 catalytic cracking Methods 0.000 description 2
- 239000003085 diluting agent Substances 0.000 description 2
- HNPSIPDUKPIQMN-UHFFFAOYSA-N dioxosilane;oxo(oxoalumanyloxy)alumane Chemical compound O=[Si]=O.O=[Al]O[Al]=O HNPSIPDUKPIQMN-UHFFFAOYSA-N 0.000 description 2
- 239000006185 dispersion Substances 0.000 description 2
- 238000010438 heat treatment Methods 0.000 description 2
- 238000005470 impregnation Methods 0.000 description 2
- 238000011056 performance test Methods 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- 238000005486 sulfidation Methods 0.000 description 2
- RAOIDOHSFRTOEL-UHFFFAOYSA-N tetrahydrothiophene Chemical compound C1CCSC1 RAOIDOHSFRTOEL-UHFFFAOYSA-N 0.000 description 2
- 235000012431 wafers Nutrition 0.000 description 2
- JCCCMAAJYSNBPR-UHFFFAOYSA-N 2-ethylthiophene Chemical compound CCC1=CC=CS1 JCCCMAAJYSNBPR-UHFFFAOYSA-N 0.000 description 1
- XQQBUAPQHNYYRS-UHFFFAOYSA-N 2-methylthiophene Chemical compound CC1=CC=CS1 XQQBUAPQHNYYRS-UHFFFAOYSA-N 0.000 description 1
- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 description 1
- 241000282326 Felis catus Species 0.000 description 1
- NHTMVDHEPJAVLT-UHFFFAOYSA-N Isooctane Chemical compound CC(C)CC(C)(C)C NHTMVDHEPJAVLT-UHFFFAOYSA-N 0.000 description 1
- QENGPZGAWFQWCZ-UHFFFAOYSA-N Methylthiophene Natural products CC=1C=CSC=1 QENGPZGAWFQWCZ-UHFFFAOYSA-N 0.000 description 1
- ZOKXTWBITQBERF-UHFFFAOYSA-N Molybdenum Chemical compound [Mo] ZOKXTWBITQBERF-UHFFFAOYSA-N 0.000 description 1
- 239000012494 Quartz wool Substances 0.000 description 1
- 229910021536 Zeolite Inorganic materials 0.000 description 1
- 239000002253 acid Substances 0.000 description 1
- 230000032683 aging Effects 0.000 description 1
- 229910000323 aluminium silicate Inorganic materials 0.000 description 1
- 239000007864 aqueous solution Substances 0.000 description 1
- 239000012298 atmosphere Substances 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 239000006227 byproduct Substances 0.000 description 1
- 229910052799 carbon Inorganic materials 0.000 description 1
- 238000004517 catalytic hydrocracking Methods 0.000 description 1
- 239000007795 chemical reaction product Substances 0.000 description 1
- 229910017052 cobalt Inorganic materials 0.000 description 1
- 239000010941 cobalt Substances 0.000 description 1
- GUTLYIVDDKVIGB-UHFFFAOYSA-N cobalt atom Chemical compound [Co] GUTLYIVDDKVIGB-UHFFFAOYSA-N 0.000 description 1
- 238000007796 conventional method Methods 0.000 description 1
- 238000005336 cracking Methods 0.000 description 1
- 230000007423 decrease Effects 0.000 description 1
- 230000001419 dependent effect Effects 0.000 description 1
- 238000009826 distribution Methods 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- 238000011066 ex-situ storage Methods 0.000 description 1
- 239000012530 fluid Substances 0.000 description 1
- 238000011010 flushing procedure Methods 0.000 description 1
- 239000008187 granular material Substances 0.000 description 1
- 229910021476 group 6 element Inorganic materials 0.000 description 1
- 230000006872 improvement Effects 0.000 description 1
- 238000011065 in-situ storage Methods 0.000 description 1
- 230000003993 interaction Effects 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 239000011159 matrix material Substances 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 239000004005 microsphere Substances 0.000 description 1
- 239000011733 molybdenum Substances 0.000 description 1
- 150000008116 organic polysulfides Chemical class 0.000 description 1
- 125000001741 organic sulfur group Chemical group 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 238000011403 purification operation Methods 0.000 description 1
- 239000000376 reactant Substances 0.000 description 1
- 238000009877 rendering Methods 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- HBMJWWWQQXIZIP-UHFFFAOYSA-N silicon carbide Chemical compound [Si+]#[C-] HBMJWWWQQXIZIP-UHFFFAOYSA-N 0.000 description 1
- 229910010271 silicon carbide Inorganic materials 0.000 description 1
- 239000002002 slurry Substances 0.000 description 1
- KKCBUQHMOMHUOY-UHFFFAOYSA-N sodium oxide Chemical compound [O-2].[Na+].[Na+] KKCBUQHMOMHUOY-UHFFFAOYSA-N 0.000 description 1
- 229910001948 sodium oxide Inorganic materials 0.000 description 1
- 229910001220 stainless steel Inorganic materials 0.000 description 1
- 239000010935 stainless steel Substances 0.000 description 1
- 239000000758 substrate Substances 0.000 description 1
- 150000003463 sulfur Chemical class 0.000 description 1
- 239000003826 tablet Substances 0.000 description 1
- 238000004227 thermal cracking Methods 0.000 description 1
- 150000003577 thiophenes Chemical class 0.000 description 1
- 239000010457 zeolite Substances 0.000 description 1
Classifications
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
- B01J37/00—Processes, in general, for preparing catalysts; Processes, in general, for activation of catalysts
- B01J37/20—Sulfiding
-
- B—PERFORMING OPERATIONS; TRANSPORTING
- B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
- B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
- B01J23/00—Catalysts comprising metals or metal oxides or hydroxides, not provided for in group B01J21/00
- B01J23/38—Catalysts comprising metals or metal oxides or hydroxides, not provided for in group B01J21/00 of noble metals
- B01J23/40—Catalysts comprising metals or metal oxides or hydroxides, not provided for in group B01J21/00 of noble metals of the platinum group metals
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G45/00—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds
- C10G45/02—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing
- C10G45/04—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing characterised by the catalyst used
- C10G45/10—Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbons; Hydrofinishing characterised by the catalyst used containing platinum group metals or compounds thereof
Definitions
- the present invention relates to a method for treating a hydrogenation catalyst and to the use of the treated catalyst in the selective hydrogenation of sulfur-containing compounds in an olefinic gasoline.
- Gasoline stock may be produced by fluid catalytic cracking (FCC) or thermal cracking of higher boiling liquid hydrocarbon fractions.
- FCC fluid catalytic cracking
- Catalytically cracked gasoline currently forms a major part of the gasoline product pool in the United States.
- the sulfur content of the gasoline is reduced, usually by hydrotreating, e.g., hydrodesulfurization, . in order to meet product specifications or to ensure compliance with environmental regulations, both of which are expected to become more stringent in the future, possibly permitting no more than about 300 ppmw sulfur in motor gasoline.
- the newly enacted U.S. government regulation requires sulfur in motor gasoline to be at or below 30 ppmw by the year 2004. Low sulfur levels result in reduced emissions of CO, NO x and hydrocarbons .
- Naphthas and other light fractions such as heavy cracked gasoline may be hydrodesulfurized by passing the feed over a hydrodesulfurization catalyst at elevated temperature and somewhat elevated pressure in a hydrogen atmosphere.
- a hydrodesulfurization catalyst which has been widely used for this operation is a combination of a Group VIII and a Group VI element, e.g., a mixture of cobalt and molybdenum, on a substrate such as alumina, silica- alumina, crystalline aluminosilicate (zeolite), and the like.
- the product may be fractionated, or simply flashed, to release by-product hydrogen sulfide and collect the now sweetened gasoline.
- a method for treating a catalyst comprises : a) providing a catalyst for the selective hydrogenation of sulfur-containing compounds in an olefinic gasoline, the catalyst possessing a catalytically effective amount of at least one noble metal on an acidic amorphous silica-alumina support having a silica content of not more than about 40% by weight; and, b) contacting said catalyst with a sulfiding agent and ⁇ ydrogen under sulfiding conditions to provide an activated catalyst having a higher activity and selectivity for hydrogenation of sulfur-containing compounds than the unsulfided catalyst.
- Treating the noble metal hydrogenation catalyst in accordance with the method of this invention increases catalyst activity and selectivity for hydrogenation of sulfur-containing compounds as opposed to hydrogenation of olefinic hydrocarbon components of the gasoline, thereby providing improved conversion of sulfur- containing compounds in the removal from gasoline stock with less reduction of octane number.
- FIG. 1 is a graph illustrating the improved hydrogenation performance of sulfided PdPt/silica-alumina catalyst as opposed to untreated PdPt/silica-alumina catalyst .
- the catalyst described herein is- useful for the selective hydrogenation of unsaturated organic sulfur- containing compounds such as thiophene or thiophene derivatives (methylthiophene, ethylthiophene, and the like) into corresponding saturated compounds (e.g., tetrahydrothiophene) , which have higher boiling points.
- unsaturated organic sulfur- containing compounds such as thiophene or thiophene derivatives (methylthiophene, ethylthiophene, and the like) into corresponding saturated compounds (e.g., tetrahydrothiophene) , which have higher boiling points.
- saturated sulfur-containing compounds are more easily removed from the olefinic gasoline by subsequent distillation, rendering a substantially sulfur free overhead product while concentrating the sulfur compounds in a bottom fraction that can subsequently be subjected to desulfurization.
- Use of the catalyst described herein enables a larger fraction of the original gasoline feedstock to be separated as a substantially sulfur free overhead
- the catalyst can be in the form of extrudates, pellets, spheres, granules, etc. More particularly, the catalyst includes a catalytically effective amount of at least one noble metal on an acidic amorphous silica-alumina support containing not more than about 40% silica by weight.
- the noble metal is selected from platinum, palladium, rhodium, ruthenium, osmium and iridium and their mixtures.
- the catalyst may also contain one or more non-noble metal components, e.g., Cu, Zn, Mn, Re, Ag, Sn, Au, Fe, Co, Ni, K, Ca, B, P, Mo, W, Cr, or Tc.
- non-noble metal components e.g., Cu, Zn, Mn, Re, Ag, Sn, Au, Fe, Co, Ni, K, Ca, B, P, Mo, W, Cr, or Tc.
- the acidic amorphous silica-alumina catalyst support utilized herein contains not more than about 40, preferably not more than about 30, and more preferably not more than about 15, weight percent of silica. Within the foregoing limits, the support contains at least that amount of silica which will provide surface acid sites on the support. This amount of silica will ordinarily constitute not less than about 0.1, and preferably not less than about 0.5, weight percent of the silica-alumina support.
- the strong to weak acidity ratio (SWAR) of the silica-alumina support can advantageously range from about 0.1 to about 1.0, preferably from about 0.2 to about 0.8 and more preferably from about 0.25 to about 0.75.
- the silica-alumina support herein contains not more than about 0.2% carbon, not more than about 0.01% iron oxide and not more than about 0.01% sodium oxide.
- the support possesses an average particle size of from about 40 to about 60 ⁇ , a BET surface area of from about 10 m 2 /g to about 500 m 2 /g and a pore volume ranging from about 0.1 ml/g to about 0.90 ml/g.
- Suitable acidic amorphous silica-alumina supports include the SIRALOX products available from Sasol GmbH, Hamburg, Germany which are supplied in powder, extrudate, pellet, tablet and microsphere forms, all of which are useful herein.
- the silica in these products is substantially uniformly distributed throughout the silica-alumina matrix, an advantageous feature for the support employed in the catalyst of this invention.
- the noble metal (s) can be loaded onto the support by any conventional method.
- the support in the case of a PdPt combination, can be impregnated with aqueous solutions of platinumtetraamine nitrate, Pt (NH 3 ) 4 (N0 3 ) 2 and palladiumtetraamine nitrate, Pd (NH 3 ) 4 (N0 3 ) 2 and then dried and calcined to leave bimetallic PdPt deposited on the support.
- the total loading of. noble metal can range from about 0.1% to about 5%, and preferably from about 0.5% to about 1.5% by weight based on total catalyst weight.
- any ratio can be suitably employed.
- the Pd/Pt weight ratio can range from about 1/5 to about 5/1, more preferably from about 1/4 to about 4/1 and most preferably from about 2/1 to about 3.5/1.
- any of the optional non-noble metals referred to above can be present at levels, including their mixtures, of from about 0.05 to about 5, and preferably from about 0.1 to about 2, weight percent based on total catalyst weight.
- the catalyst is treated prior to its use in hydrogenation by contacting the catalyst with an effective amount of a sulfiding agent and hydrogen under sulfiding conditions to produce an activated catalyst having a higher activity and selectivity for hydrogenation of sulfur-containing compounds than for hydrogenation of olefinic hydrocarbon components of the feed as compared with the unsulfided catalyst.
- Sulfiding can be performed on a fresh catalyst or, alternatively, on a catalyst previously used in hydrodesulfurization.
- the catalyst is contacted with hydrogen and a sulfiding feed including a sulfiding agent and a solvent. The nature of the solvent depends on the type of sulfiding agent used.
- Preferred solvents for the sulfidation feed include hydrocarbons such as gasoline fractions containing one or more of hexane, heptane, octane and/or nonane, with or without aromatic components such as benzene, toluene, xylene and the like.
- the sulfiding feed includes from about 0.05% to about 10% by weight of a sulfiding agent, and preferably from about' 0.5% to about 5.0% by weight of a sulfiding agent, which can be selected from sulfur, carbon disulfide, substituted or unsubstituted thiophenic compounds, e .g. , .
- thiophene and compounds having the formula R-(S) n -R' (I) wherein n is an integer of from 1 to about 6, and R and R' are each individually selected from hydrogen and an organic group containing from 1 to about 10 carbon atoms, the organic group being selected from branched or straight chain alkyl groups, naphthenic groups, aryl groups and alkaryl groups.
- One or more of the sulfiding agents can be incorporated into the sulfiding feed individually or combined.
- sulfiding agents of formula (I) include hydrogen sulfide, methyl mercaptan, ethyl mercaptan, butyl mercaptan, dimethyl sulfide, dimethyl disulfide and organic polysulfides such as ditertbutyl polysulfide, ditertnonyl polysulfide and ditertdodecyl polysulfide, the. aforementioned polysulfides being available from Elf Aquitaine of Courbevoie, France, under the designations TPS-54, TPS-37 and TPS-32, respectively.
- the sulfiding conditions include a temperature of from about 120°C to about 420°C, preferably from about 200°C to about 400°C, more preferably from about 250°C to about 350°C, and most preferably from about 330°C to about 350°C, a pressure of up to about 900 psig, preferably up to about 500 psig, more preferably from about 100 to about 400 psig, and a hydrogen flow of from about 1 cc/g-catalyst/min to about 100 cc/g-catalyst/min, preferably from about 2.5 to about 30 cc/g- catalyst/minute .
- the feed rate of sulfiding feed can be from about 0.02 to about 5 g-feed/g-catalyst/min, preferably from about 0.05g feed/g-catalyst/min to about 3.5 g-feed/g- catalyst/min.
- Sulfiding of the catalyst can be performed in situ or ex situ, i.e., in the same reactor in which the selective hydrogenation is to be performed or in a separate reactor.
- the catalyst is pre-wetted with the sulfiding feed before heating. The temperature of the system is then raised at the rate of from about 0.1°C to about 10°C.
- the catalyst is then held at that temperature for at least about 0.5 hours, preferably for a period of time ranging from about 2 hours to about 10 hours.
- the temperature of the system is reduced to about 150°C while maintaining the sulfiding feed flow and hydrogen flow.
- the sulfiding feed is then flushed out of the system.
- the hydrogenation feed can be used for flushing the system which is then adjusted to the hydrogenation temperature and pressure.
- the feed to the hydrogenation process of this invention is a sulfur-containing olefinic gasoline.
- Feeds of this type include light naphthas typically having a boiling range of about C 6 to 330°F, full range naphthas typically having a boiling range of about C 5 to 420°F, heavier naphtha fractions boiling in the range of about 260°F to 412°F, or heavy gasoline fractions boiling at, or at least within, the range of about 330°F to 500°F, preferably about 330°F to 412°F.
- the hydrogenation process can be operated upon the entire gasoline fraction obtained from the catalytic cracking unit or with just a part of it, depending on the amount and the nature of the sulfur compounds present.
- the cut point between the treated and untreated fractions can vary according to the sulfur compounds present, but usually a cut point in the range of from about 100°F (38°C) to about 300°F (150°C) , more usually i • the range of about 200°F (93°C) to about 300°F (150°C) , will be suitable.
- the exact cut point selected will depend on the sulfur specification for the gasoline product as well as on the type of sulfur compounds present. Lower cut points will typically be necessary for lower product sulfur specifications.
- the sulfur which is present in components boiling below about 150°F (65°C) is mostly in the form of mercaptans which can be removed by extractive type processes such as Merox but hydrotreating is appropriate for the removal of thiophene and other cyclic sulfur compounds present in higher boiling components, e.g., component fractions boiling above about 180°F (82°C) .
- Treatment of the lower boiling fraction in an extractive type process coupled with hydrotreating of the higher boiling component thus represents an embodiment of the present invention.
- Higher cut points will be preferred in order to minimize the amount of feed which is passed to the hydrotreater and the final selection of cut point together with other process options such as the extractive type desulfurization will therefore be made in accordance with the product specifications, feed constraints and other factors.
- the sulfur content of these catalytically cracked fractions will depend on the sulfur content of the feed to the cracker as well as on the boiling range of the selected fraction used as the feed in the process. Lighter fractions, for example, will tend to have lower sulfur contents than the higher boiling fractions. As a practical matter, the sulfur content of the olefinic gasoline feed herein will exceed 50 ppmw, will usually be in excess of 100 ppmw and in most cases will be in excess of about 500 ppmw. For the fractions which have 95 percent points over about 380°F (193°C) , the sulfur content may exceed about 1000 ppmw and may be as high as 4000 or 5000 ppmw or even higher, as shown below.
- the nitrogen content is not as characteristic of the feed as the sulfur content and is preferably not greater than about 20 ppmw although higher nitrogen levels typically up to about 50 ppmw may be found in certain higher boiling feeds with 95 percent points in excess of about 380°F (193°C) .
- the nitrogen level will, however, usually not be greater than 250 or 300 ppmw.
- the feed to the selective hydrogenation step will be olefinic, with an olefin content of at least 5% by weight and more typically in the range of 10 to 20% by weight, e.g. 15-20% by weight.
- the selective hydrogenation of the sulfur- containing compounds in the feed is carried out with the aforedescribed hydrogenation catalyst under conditions which result in the conversion of at least- some of the sulfur-containing compounds in the feed to less volatile saturated compounds to produce a product comprising a normally liquid fraction boiling in substantially the same boiling range as the feed to this step.
- the sulfur-containing compound to be removed is thiophene, ' which boils at about 84.4°C.
- the thiophene is converted by selective hydrogenation into tetrahydrothiophene, which boils at about 121°C.
- the sulfur content of the product fraction is associated with higher boiling compounds which are more easily removed by subsequent distillation.
- the temperature of the selective hydrogenation step is suitably from about 300°F to 850°F (about 150°C to 454°C), preferably about 350°F to 650°F (about 180°C to 427°C) with the exact selection dependent on the hydrogenation desired for a given feed and catalyst. These temperatures are average temperatures and will, of course, vary according to the feed and other reaction paramenters including, for example, hydrogen pressure and catalyst activity.
- the hydrogenation can be performed in any one of a variety of reactor systems such as catalytic distillation, fixed bed, ebulliated bed, fluidized bed, moving bed, slurry reactor, and the like.
- reactor systems such as catalytic distillation, fixed bed, ebulliated bed, fluidized bed, moving bed, slurry reactor, and the like.
- the reactor may contain more than one bed.
- low to moderate pressures may be used, typically from about 50 to 1500 psig (about 400 to 13000 kPa) , preferably about 200 to 800 psig (about 1700 to 7000 kPa) .
- Pressures are total system pressure. Pressure will normally be chosen to maintain the desired aging rate -for the catalyst in use.
- the space velocity for the hydrogenation step overall is typically about 0.1 to 50 LHSV (hr- 1 ) , preferably about 0.2 to about 30, e.g., 3 to 25, LHSV(hr- 1 ), based on the total feed and the total catalyst volume.
- the hydrogen to hydrocarbon ratio in the feed is typically about 500 to 5000 SCF/Bbl (about 90 to 900 n.1.1 -1 .), usually about 1000 to 2500
- Examples 1 and 3 are directed to the catalysts of the present invention in an unsulfided condition.
- Examples 2 and 4 are directed to the sulfidation of the catalysts of Examples 1 and 3, respectively. With respect to Examples 1-4, the following methods, materials and equipment were employed.
- a formulated gasoline feed illustrative of an FCC olefinic gasoline was used for the measurement of catalyst activity.
- the formulated gasoline contained two olefins, i.e., octene-1 and 2, 4 , 4-trimethylpentene-l (TMP) , together with toluene, thiophene, pyridine and n- heptane.
- TMP 4-trimethylpentene-l
- the olefins were chosen to represent olefin distribution of typical cracked naphtha gasolines, i.e., from about 10 to about 20% by weight terminal olefins and from about 80 to about 90% by weight branched olefins.
- Toluene was chosen to represent the aromatics contained in a typical olefinic gasoline.
- Thiophene was used to represent organic sulfur components contained in cracked naphtha gasoline.
- Pyridine was included to represent the basic components of an FCC gasoline.
- the amount of total olefins was varied in the range of from about 10 to about 40 weight %.
- the amount of aromatics was ' fixed to about 40 weight %.
- the amount of sulfur in the feed was varied in the range of from about 500 to about 2500 ppm wt.
- the amount of pyridine was varied in the range of from about 50 to about 250 ppm wt.
- Catalyst in the form of pellets or small particles mixed with a diluent, e.g., silicon carbide, was loaded into the reactor.
- the reactor was constructed of stainless steel (OD: V, wall thickness of 1/16", length: 8") .
- Typical diluent to catalyst ratio was 5-15 wt/wt .
- the catalyst was positioned in between two quartz wool plugs to prevent the catalyst from being carried away.
- the reactants (olefinic gasoline feed and hydrogen) were fed from the bottom.
- the liquid feed was delivered by an Eldex metering pump (Eldex Laboratories Inc., Napa, CA) .
- Hydrogen was controlled by a Brooks mass flow controller (Brooks Instrument, Hatfield, PA) .
- Reactor pressure was controlled by a Mighty-
- Mite backpressure regulator (Grove Valve & Regulator Co., Oakland, CA) . Reaction products were analyzed by an online gas chromatography (GC) unit.
- GC gas chromatography
- the reactor was charged with 1 to 3g of catalyst.
- the feed was introduced into the reactor at room temperature at a rate of from 0. Ig/min to 2g/min to first pre-wet the catalyst.
- Hydrogen was introduced at a rate of from lOcc/min to 200cc/min and the reactor was pressurized to a hydrogenation reaction pressure of 440 psig.
- the temperature was then increased at the rate of from about 0.2°C/min to 5°C/min until the reaction temperature of 215°C was reached.
- the entire reactor and pre-heating feed line were immersed in a fluid bed sand bath to achieve uniform temperature control.
- PdPt/silica-alumina catalyst of the present invention designated PdPt/SA-1
- SA-1 silica-alumina support from Condea Vista Company
- Silica-alumina SA-1 20g was impregnated by incipient wetness with a solution containing 0.1195g of platinumtetraamine nitrate (Alfa Aesar, 99.9% metal purity) and 0.5369g of palladiumtetraamine nitrate (Alfa Aesar, 99.9% metal purity) to give 0.3 wt% Pt and 0.9 wt% Pd.
- the mixture was dried at 110°C for two hours before being calcined at 500°C in air for 3 hours. This gave 1.2%PdPt/SA-l .
- Wafers of 1mm thick and 20-30 mm in diameter made by pressurizing the catalyst powder were crushed and sieved to have particles in the range of 0.6-1.2 mm. Catalyst particles in the size range of 0.6-1.2mm were used for the hydrogenation performance test.
- the olefinic gasoline feed in the reactor was vented and the reactor then purged with nitrogen until it was dry.
- the catalyst was then pre-wetted with a sulfiding feed containing 0.5% to 5.0% by weight of dimethyl disulfide in n-heptane.
- the flow rate of sulfiding feed was 0.05 g-feed/g- catalyst/min to 0.5 g-feed/g-catalyst/min.
- Hydrogen was then introduced into the reactor at a flow rate of from 5 cc/g-catalyst/min to 150 cc/g-catalyst/min and the temperature of the system raised at the rate of from 0.2°C/min to 5.0°C/min until the sulfiding temperature of 250°C to 350°C was reached.
- the system pressure was 100 to 400 psig.
- the sulfiding reaction was held at these conditions of temperature and pressure for from 4 to 12 hours .
- PdPt/silica-alumina catalyst of the present invention was prepared by incipient wetness impregnation of a low silica silica- alumina from Condea Vista Company, designated SA-2, containing 10% of Si0 2 .
- the SA-2 support 20g, was impregnated with a solution containing 0.1195g of platinumtetraamine nitrate (Alfa Aesar, 99.9% metal purity) and 0.5369g of palladiumtetraamine nitrate (Alfa Aesar, 99.9% metal purity) to give 0.3 wt% Pt and 0.9 wt% Pd.
- the catalyst was tested for activity in the reactor described above. Both hydrogenation activity and selectivity were determined. The results are set forth below in Table 1 below.
- EXAMPLE 4 The 1.2% PdPt/SA-2 catalyst of Example 3 was sulfided in accordance with the following procedure.
- the olefinic gasoline feed in the reactor was vented and the reactor then purged with nitrogen until it was dry.
- the catalyst was then pre-wetted with a sulfiding feed containing 0.5% to 5.0% by weight of dimethyl disulfide in n-heptane.
- the flow rate of sulfiding feed was 0.05 g-feed/g- catalyst/min to 0.5 g-feed/g-catalyst/min.
- Hydrogen was then introduced into the reactor at a flow rate of from 5 cc/g-catalyst/min to 150 cc/g-catalyst/min and the temperature of the system raised at the rate of from
- the system was cooled down to below 200°C and the sulfiding feed was flushed out of the system at 100°-200°C.
- the olefinic gasoline feed was introduced along with hydrogen and the reactor conditions were then adjusted for hydrogenation.
- the catalyst designated 1.2% PdPt/SA-2-S, was then tested with respect to both HDS and HYD activity. The results are set forth below in Table 1.
- Table 1 summarizes the HDS hydrogenation activity of the catalysts exemplified above (as measured by the hydrogenation of thiophene) as compared with the HYD hydrogenation activity (as measured by the hydrogenation of 2, 4, 4-trimethylpentene-l).
- Example 2 1.2%PdPt/SA-l- 21.3 3.07 6.94 S (catalyst of Example 1 sulfided)
- Example 4 1.2%PdPt/SA-2- 12.96 1.94 * 5.44 S (catalyst of Example 3 sulfided)
- the sulfided 1.2% PtPd/SA-1-S catalyst of Example 2 was more than 55% more active with respect to hydrogenation of thiophene than the same catalyst in an unsulfided condition (Example 1) Moreover, the sulfided 1.2% PdPt/SA-1-S catalyst of Example 2 had a selectivity for hydrogenation of thiophene (k HDS /k HYD ) which was more than 79% better than that of the same PdPt/SA-1 catalyst in an unsulfided condition (Example 1) .
- the sulfided 1.2% PdP ' t/SA-2-S catalyst of Example 4 was more than 31% more active with respect to hydrogenation of thiophene than the corresponding unsulfided 1.2% PdPt/SA-2 catalyst of Example 3.
- the selectivity of the sulfided catalyst of Example 4 for the hydrogenation of thiophene was about 31% better than that of the corresponding unsulfided catalyst of Example 3.
- FIG. 1 illustrates the performance of the tested catalysts for treating gasoline by charting the hydrogenation activity k HDS relative to the hydrogenation activity k HyD .
- the unsulfided catalysts of Examples 1 and 3 lie on line A. Data points above line A indicate that the catalysts are more active and selective. The arrows indicate the improvement in activity and selectivity accomplished by the sulfiding method herein.
- the data points for the sulfided catalysts of Examples 2 and 4 lie on line B, which is above line A, indicating the improved performance in hydrogenation achieved by sulfiding the PdPt/silica-alumina catalysts according to the present invention.
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PCT/US2002/012119 WO2002083303A1 (fr) | 2001-04-16 | 2002-04-16 | Procede de traitement d'un catalyseur et utilisation du catalyseur traite pour l'hydrogenation selective de composes a teneur en soufre |
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CN106622268A (zh) * | 2015-10-29 | 2017-05-10 | 中国石油化工股份有限公司 | 一种浆态床加氢催化剂及其制备方法 |
Citations (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4070272A (en) * | 1976-06-14 | 1978-01-24 | Uop Inc. | Hydrodesulfurization of hydrocarbon distillate with a catalyst composite of carrier, Pt/Pd, Rh and Sn |
WO1998035754A1 (fr) * | 1997-02-13 | 1998-08-20 | Engelhard Corporation | Procede d'hydrogenation, d'hydro-isomerisation et/ou d'hydrodesulfuration d'une charge renfermant un contaminant sulfure |
JPH11253805A (ja) * | 1998-03-11 | 1999-09-21 | Dainippon Ink & Chem Inc | 予備硫化触媒の製造方法 |
-
2002
- 2002-04-16 WO PCT/US2002/012119 patent/WO2002083303A1/fr not_active Application Discontinuation
Patent Citations (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4070272A (en) * | 1976-06-14 | 1978-01-24 | Uop Inc. | Hydrodesulfurization of hydrocarbon distillate with a catalyst composite of carrier, Pt/Pd, Rh and Sn |
WO1998035754A1 (fr) * | 1997-02-13 | 1998-08-20 | Engelhard Corporation | Procede d'hydrogenation, d'hydro-isomerisation et/ou d'hydrodesulfuration d'une charge renfermant un contaminant sulfure |
JPH11253805A (ja) * | 1998-03-11 | 1999-09-21 | Dainippon Ink & Chem Inc | 予備硫化触媒の製造方法 |
Non-Patent Citations (1)
Title |
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PATENT ABSTRACTS OF JAPAN vol. 1999, no. 14 22 December 1999 (1999-12-22) * |
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
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CN106622268A (zh) * | 2015-10-29 | 2017-05-10 | 中国石油化工股份有限公司 | 一种浆态床加氢催化剂及其制备方法 |
CN106622268B (zh) * | 2015-10-29 | 2019-04-16 | 中国石油化工股份有限公司 | 一种浆态床加氢催化剂及其制备方法 |
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