CA2467879A1 - Multi-stage hydrodesulfurization of cracked naphtha streams with interstage fractionation - Google Patents
Multi-stage hydrodesulfurization of cracked naphtha streams with interstage fractionation Download PDFInfo
- Publication number
- CA2467879A1 CA2467879A1 CA002467879A CA2467879A CA2467879A1 CA 2467879 A1 CA2467879 A1 CA 2467879A1 CA 002467879 A CA002467879 A CA 002467879A CA 2467879 A CA2467879 A CA 2467879A CA 2467879 A1 CA2467879 A1 CA 2467879A1
- Authority
- CA
- Canada
- Prior art keywords
- oxide
- organically bound
- bound sulfur
- sulfur
- group
- 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.)
- Granted
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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
- 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
- C10G65/04—Treatment of hydrocarbon oils by two or more hydrotreatment processes only plural serial stages only including only refining 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
- 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
- C10G45/06—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 nickel or cobalt metal, or compounds thereof
- C10G45/08—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 nickel or cobalt metal, or compounds thereof in combination with chromium, molybdenum, or tungsten metals, or compounds thereof
-
- 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
- C10G2300/4006—Temperature
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
- C10G2300/40—Characteristics of the process deviating from typical ways of processing
- C10G2300/4012—Pressure
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- 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
- C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
- C10L1/00—Liquid carbonaceous fuels
- C10L1/04—Liquid carbonaceous fuels essentially based on blends of hydrocarbons
- C10L1/06—Liquid carbonaceous fuels essentially based on blends of hydrocarbons for spark ignition
Abstract
A process for the selective hydrodesulfurization of olefinic naphtha streams containing a substantial amount of organically bound sulfur and olefins. The olefinic naphtha stream is selectively hydrodesulfurized in a first sulfur removal stage and resulting product stream, which contains hydrogen sulfide and organosulfur is fractionated at a temperature to produce a light fractio n containing less than about 100 wppm organically bound sulfur and a heavy fraction containing greater than about 100 wppm organically bound sulfur. Th e light fraction is stripped of at least a portion of its hydrogen sulfide and can be collected or passed to gasoline blending. The heavy fraction is passe d to a second sulfur removal stage wherein at least a portion of any remaining organically bound sulfur is removed.
Claims (15)
1. A process for hydrodesulfurizing olefinic naphtha feedstreams and retaining a substantial amount of the olefins, which feedstream boils in the range of about 50°F (10°C) to about 450°F (232°C) and contains substantial amounts of organically bound sulfur and olefins, which process comprises:
a) hydrodesulfurizing the feedstream in a first sulfur removal stage in the presence of a hydrogen and a hydrodesulfurization catalyst, at hydrodesulfuriza-tion reaction conditions including temperatures from about 232°C
(450°F) to about 427°C (800°F), pressures of about 60 to 800 psig, and hydrogen treat gas rates of about 1000 to 6000 standard cubic feet per barrel, to convert at least about 50 wt% of the organically bound sulfur to hydrogen sulfide and to produce a first product stream containing from about 100 to about 1,000 wppm organically bound sulfur;
b) fractionating said product stream into a light fraction and a heavy fraction, wherein the fractionation cut point is at a temperature such that the light fraction contains less about 100 wppm of organically bound sulfur and some hydrogen sulfide and the heavy fraction contains the remainder of the organically bound sulfur;
c) stripping the light fraction of at least a portion of its hydrogen sulfide;
d) conducting the stripped light fraction away from the process;
e) conducting the heavy fraction to a second sulfur removal stage wherein at least a portion of the remaining organically bound sulfur is removed.
a) hydrodesulfurizing the feedstream in a first sulfur removal stage in the presence of a hydrogen and a hydrodesulfurization catalyst, at hydrodesulfuriza-tion reaction conditions including temperatures from about 232°C
(450°F) to about 427°C (800°F), pressures of about 60 to 800 psig, and hydrogen treat gas rates of about 1000 to 6000 standard cubic feet per barrel, to convert at least about 50 wt% of the organically bound sulfur to hydrogen sulfide and to produce a first product stream containing from about 100 to about 1,000 wppm organically bound sulfur;
b) fractionating said product stream into a light fraction and a heavy fraction, wherein the fractionation cut point is at a temperature such that the light fraction contains less about 100 wppm of organically bound sulfur and some hydrogen sulfide and the heavy fraction contains the remainder of the organically bound sulfur;
c) stripping the light fraction of at least a portion of its hydrogen sulfide;
d) conducting the stripped light fraction away from the process;
e) conducting the heavy fraction to a second sulfur removal stage wherein at least a portion of the remaining organically bound sulfur is removed.
2. The process of claim 1 wherein the cut point is at a temperature wherein the organically bound sulfur level of the light fraction is equal to or less than about 50 wppm.
3. The process of claim 1 wherein the naphtha feedstream contains from about 1,000 to about 6,000 wppm sulfur and up to 60 wt% olefins concentration.
4. The process of claim 1 wherein the hydrotreating catalyst is comprised of at least one Group VIII metal, and at least one Group VI metal on an inorganic metal support, wherein the Groups are selected from the Periodic Table of the Elements.
5. The process of claim 4 wherein the inorganic oxide support is selected from the group consisting of zeolites, alumina, silica, titanic, calcium oxide, strontium oxide, barium oxide, carbons, zirconia, diatomaceous earth, cerium oxide, lanthanum oxide, neodynium oxide, yttrium oxide, and praesodynium oxide; chromic, thorium oxide, urania, niobia, tantala, tin oxide and zinc oxide.
6. The process of claim 5 wherein the Group VIII metal is selected from Ni and Co and the Group VI metal is Mo.
7. The process of claim 6 wherein the amount of Group VIII metal in the hydrotreating catalyst is from about 1 to 5 wt% and the amount of Group VI
metal is from about 1 to 15 wt%, which weight percents are based on the total weight of the catalyst.
metal is from about 1 to 15 wt%, which weight percents are based on the total weight of the catalyst.
8. The process of claim 1 wherein the hydrodesulfurization catalyst is comprised of a Mo catalytic component, a Co catalytic component and a support component, with the Mo component being present in an amount of from 1 to 10 wt% calculated as MoO3 and the Co component being present in an amount of from 0.1 to 5 wt% calculated as CoO, with a Co/Mo atomic ratio of 0.1 to 1.
9. A process for hydrodesulfurizing olefinic naphtha feedstreams and retain-ing a substantial amount of olefins, which feedstreams boil in the range of about 50°F to about 430°F and contain from about 1,500 to 5,000 wppm organically bound sulfur and at least about 5 wt% olefins, which process comprises:
a) hydrodesulfurizing said feedstream in a first sulfur removal stage in the presence of a hydrodesulfurization catalyst comprised of at least one Group VIII metal and at least one Group Vl metal, at reaction conditions including temperatures from about 450°F to about 800°F, pressures of about 60 to 150 psig, and hydrogen treat gas rates of about 2000 to 4000 standard cubic feet per barrel, wherein at least about 50 wt% of the organically bound sulfur is converted to hydrogen sulfide and to produce a first product stream containing from about 100 to 1,000 wppm organically bound sulfur;
b) fractionating said first product stream into a light fraction and a heavy fraction, wherein the fractionation cut point is at a temperature such that the light fi-action contains less than about 100 wppm organically bound sulfur and hydrogen sulfide and the heavy fraction contains the remainder of the organically bound sulfur from said first product stream;
c) shipping the light fraction of at least a portion of its hydrogen sulfide;
d) collecting said snipped light fraction;
e) hydrodesulfurizing said heavy fraction in a second sulfur removal stage in the presence of a hydrodesulfurization catalyst comprised of at least one Group VIII metal and at least one Group VI metal at hydrodesulfurization conditions to remove at least a portion of the organically bound sulfur of said heavy fraction, and to produce a second product stream; and f) combining said stripped light fraction with said second product stream.
a) hydrodesulfurizing said feedstream in a first sulfur removal stage in the presence of a hydrodesulfurization catalyst comprised of at least one Group VIII metal and at least one Group Vl metal, at reaction conditions including temperatures from about 450°F to about 800°F, pressures of about 60 to 150 psig, and hydrogen treat gas rates of about 2000 to 4000 standard cubic feet per barrel, wherein at least about 50 wt% of the organically bound sulfur is converted to hydrogen sulfide and to produce a first product stream containing from about 100 to 1,000 wppm organically bound sulfur;
b) fractionating said first product stream into a light fraction and a heavy fraction, wherein the fractionation cut point is at a temperature such that the light fi-action contains less than about 100 wppm organically bound sulfur and hydrogen sulfide and the heavy fraction contains the remainder of the organically bound sulfur from said first product stream;
c) shipping the light fraction of at least a portion of its hydrogen sulfide;
d) collecting said snipped light fraction;
e) hydrodesulfurizing said heavy fraction in a second sulfur removal stage in the presence of a hydrodesulfurization catalyst comprised of at least one Group VIII metal and at least one Group VI metal at hydrodesulfurization conditions to remove at least a portion of the organically bound sulfur of said heavy fraction, and to produce a second product stream; and f) combining said stripped light fraction with said second product stream.
10. The process of claim 9 wherein the inorganic oxide support is selected from the group consisting of zeolites, alumina, silica, titania, calcium oxide, strontium oxide, barium oxide, carbons, zirconia, diatomaceous earth, cerium oxide, lanthanum oxide, neodymium oxide, yttrium oxide, and praesodynium oxide; chromia, thorium oxide, urania, niobia, tantala, tin oxide and zinc oxide.
11. The process of claim 9 wherein the Group VIII metal is selected from Ni and Co and the Group VI metal is Mo.
12. The process of claim 10 wherein the amount of Group VIII metal in the hydrotreating catalyst is from about 1 to 5 wt% and the amount of Group VI
metal is from about 1 to 15 wt%, which weight percents are based on the total weight of the catalyst.
metal is from about 1 to 15 wt%, which weight percents are based on the total weight of the catalyst.
13. The process of claim 9 wherein the hydrodesulfurization catalyst is comprised of a Mo catalytic component, a Co catalytic component and a support component, with the Mo component being present in an amount of from 1 to wt% calculated as MoO3 and the Co component being present in an amount of from 0.1 to 5 wt% calculated as CoO, with a Co/Mo atomic ratio of 0.1 to 1.
14. The process of claim 9 wherein the content of organically bound sulfur in the stripped light fraction is greater than the content of organically bound sulfur in the second product stream.
15. The process of claim 9 wherein the content of organically bound sulfur in the stripped light fraction is greater than the content of organically bound sulfur in the combined stream comprised of both the stripped light fraction and the second product stream.
Applications Claiming Priority (5)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US33457201P | 2001-11-30 | 2001-11-30 | |
| US60/334,572 | 2001-11-30 | ||
| US10/274,021 US6913688B2 (en) | 2001-11-30 | 2002-10-18 | Multi-stage hydrodesulfurization of cracked naphtha streams with interstage fractionation |
| US10/274,021 | 2002-10-18 | ||
| PCT/US2002/035954 WO2003048273A1 (en) | 2001-11-30 | 2002-11-08 | Multi-stage hydrodesulfurization of cracked naphtha streams with interstage fractionation |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2467879A1 true CA2467879A1 (en) | 2003-06-12 |
| CA2467879C CA2467879C (en) | 2012-10-30 |
Family
ID=26956564
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2467879A Expired - Fee Related CA2467879C (en) | 2001-11-30 | 2002-11-08 | Multi-stage hydrodesulfurization of cracked naphtha streams with interstage fractionation |
Country Status (8)
| Country | Link |
|---|---|
| US (1) | US6913688B2 (en) |
| EP (1) | EP1461401B1 (en) |
| JP (1) | JP4423037B2 (en) |
| AU (1) | AU2002352577B2 (en) |
| CA (1) | CA2467879C (en) |
| ES (1) | ES2557984T3 (en) |
| NO (1) | NO20042963L (en) |
| WO (1) | WO2003048273A1 (en) |
Families Citing this family (19)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US7153415B2 (en) * | 2002-02-13 | 2006-12-26 | Catalytic Distillation Technologies | Process for the treatment of light naphtha hydrocarbon streams |
| US7981275B2 (en) * | 2003-10-10 | 2011-07-19 | Instituto Mexicano Del Petroleo | Catalytic composition for hydroprocessing of light and intermediate oil fractions |
| WO2005044959A1 (en) * | 2003-11-07 | 2005-05-19 | Japan Energy Corporation | Lead-free gasoline composition and method for production thereof |
| US7507328B2 (en) * | 2004-12-27 | 2009-03-24 | Exxonmobile Research And Engineering Company | Selective hydrodesulfurization and mercaptan decomposition process with interstage separation |
| US20070114156A1 (en) * | 2005-11-23 | 2007-05-24 | Greeley John P | Selective naphtha hydrodesulfurization with high temperature mercaptan decomposition |
| US7837861B2 (en) | 2006-10-18 | 2010-11-23 | Exxonmobil Research & Engineering Co. | Process for benzene reduction and sulfur removal from FCC naphthas |
| US7749375B2 (en) | 2007-09-07 | 2010-07-06 | Uop Llc | Hydrodesulfurization process |
| US7875167B2 (en) * | 2007-12-31 | 2011-01-25 | Exxonmobil Research And Engineering Company | Low pressure selective desulfurization of naphthas |
| US8894844B2 (en) | 2011-03-21 | 2014-11-25 | Exxonmobil Research And Engineering Company | Hydroprocessing methods utilizing carbon oxide-tolerant catalysts |
| US9783747B2 (en) | 2013-06-27 | 2017-10-10 | Uop Llc | Process for desulfurization of naphtha using ionic liquids |
| US9399741B2 (en) | 2013-10-09 | 2016-07-26 | Uop Llc | Methods and apparatuses for desulfurizing hydrocarbon streams |
| US10144883B2 (en) | 2013-11-14 | 2018-12-04 | Uop Llc | Apparatuses and methods for desulfurization of naphtha |
| US9850435B2 (en) | 2014-08-26 | 2017-12-26 | Exxonmobil Research And Engineering Company | Hydroprocessing with drum blanketing gas compositional control |
| FR3049955B1 (en) | 2016-04-08 | 2018-04-06 | IFP Energies Nouvelles | PROCESS FOR TREATING A GASOLINE |
| FR3057578B1 (en) | 2016-10-19 | 2018-11-16 | IFP Energies Nouvelles | PROCESS FOR HYDRODESULFURING OLEFINIC ESSENCE |
| CA3049804A1 (en) | 2017-02-21 | 2018-08-30 | Exxonmobil Research And Engineering Company | Desulfurization of a naphtha boiling range feed |
| WO2019229049A1 (en) * | 2018-05-30 | 2019-12-05 | Haldor Topsøe A/S | Process for desulfurization of hydrocarbons |
| MX2020012726A (en) * | 2018-05-30 | 2021-02-22 | Haldor Topsoe As | Process for desulfurization of hydrocarbons. |
| EP3870680A1 (en) * | 2018-10-22 | 2021-09-01 | Total Marketing Services | Deep desulphurization of low sulphur content feedstock |
Family Cites Families (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| AU513580B2 (en) | 1976-03-04 | 1980-12-11 | Amoco Corporation | The selective desulfurization of cracked naphthas |
| US6126814A (en) | 1996-02-02 | 2000-10-03 | Exxon Research And Engineering Co | Selective hydrodesulfurization process (HEN-9601) |
| US6231753B1 (en) | 1996-02-02 | 2001-05-15 | Exxon Research And Engineering Company | Two stage deep naphtha desulfurization with reduced mercaptan formation |
| US6013598A (en) | 1996-02-02 | 2000-01-11 | Exxon Research And Engineering Co. | Selective hydrodesulfurization catalyst |
| US5985136A (en) | 1998-06-18 | 1999-11-16 | Exxon Research And Engineering Co. | Two stage hydrodesulfurization process |
| US6083378A (en) | 1998-09-10 | 2000-07-04 | Catalytic Distillation Technologies | Process for the simultaneous treatment and fractionation of light naphtha hydrocarbon streams |
| US6303020B1 (en) | 2000-01-07 | 2001-10-16 | Catalytic Distillation Technologies | Process for the desulfurization of petroleum feeds |
-
2002
- 2002-10-18 US US10/274,021 patent/US6913688B2/en not_active Expired - Lifetime
- 2002-11-08 EP EP02789534.1A patent/EP1461401B1/en not_active Expired - Lifetime
- 2002-11-08 AU AU2002352577A patent/AU2002352577B2/en not_active Ceased
- 2002-11-08 CA CA2467879A patent/CA2467879C/en not_active Expired - Fee Related
- 2002-11-08 WO PCT/US2002/035954 patent/WO2003048273A1/en active Application Filing
- 2002-11-08 JP JP2003549453A patent/JP4423037B2/en not_active Expired - Fee Related
- 2002-11-08 ES ES02789534.1T patent/ES2557984T3/en not_active Expired - Lifetime
-
2004
- 2004-06-29 NO NO20042963A patent/NO20042963L/en not_active Application Discontinuation
Also Published As
| Publication number | Publication date |
|---|---|
| NO20042963L (en) | 2004-06-29 |
| EP1461401A4 (en) | 2008-12-24 |
| AU2002352577A1 (en) | 2003-06-17 |
| JP2005516078A (en) | 2005-06-02 |
| US6913688B2 (en) | 2005-07-05 |
| ES2557984T3 (en) | 2016-02-01 |
| WO2003048273A1 (en) | 2003-06-12 |
| EP1461401B1 (en) | 2015-10-21 |
| US20030106839A1 (en) | 2003-06-12 |
| JP4423037B2 (en) | 2010-03-03 |
| CA2467879C (en) | 2012-10-30 |
| AU2002352577B2 (en) | 2009-09-17 |
| EP1461401A1 (en) | 2004-09-29 |
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