US2431920A - Catalytic treatment of sulfurbearing hydrocarbon distillates - Google Patents

Catalytic treatment of sulfurbearing hydrocarbon distillates Download PDF

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Publication number
US2431920A
US2431920A US569234A US56923444A US2431920A US 2431920 A US2431920 A US 2431920A US 569234 A US569234 A US 569234A US 56923444 A US56923444 A US 56923444A US 2431920 A US2431920 A US 2431920A
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sulfur
feed
catalyst
treatment
sulfide
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US569234A
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Robert M Cole
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Shell Development Co
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Shell Development Co
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    • 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
    • C10G35/00—Reforming naphtha
    • C10G35/04—Catalytic reforming
    • C10G35/06—Catalytic reforming characterised by the catalyst used
    • 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

Definitions

  • This invention relates to a new and improved process for the treatment of cracked gasolines, thermally reformed gasolines and similar olefinic hydrocarbon distillates obtained from high sulfur petroleums and containing more than 0.10% sulfur.
  • the purpose and result of the treatment are (1) to effect a substantial reduction of the sulfur content, (2) to saturate and render innocuous certain highly unsaturated gum-forming constituents of such distillates and to saturate at least a part of the olefins if these are present, and, (3) to produce aromatic hydrocarbons in said materials by the catalytic dehydrogenation of naphthenic and cyclic olefin components thereof.
  • a further purpose and result of the process may be stated to be a substantially complete desulfurization of the material in a substantially continuous treatment with excellent catalyst life under conditions affording an improvement in the anti-knock properties of the material.
  • the process of the present invention involves passing the vapors of the sulfur-bearing cracked gasoline or similar distillate in the presence of hydrogen in contact with a preformed metal sulfide hydrogenation-dehydrogenation catalyst. It is desirable before describing the process of the invention infurther detail to point out a few basic facts which underlie such treatments. If a cracked gasoline or similar material containing various saturated and unsaturated hydrocarbons, aromatic hydrocarbons and sulfur compounds is treated under hydrogen pressure with a hydrogenation-dehydrogenation catalyst at a. low temperature, for example; in the order of 500-600 F. simple hydrogenation results. No dehydrogenation takes place and if the treatment is carried anywhere near to completion the anti-knock properties of the material are severely depreciated.
  • This simultaneous dehydrogenation tends to counteract the loss of anti-knock properties due to the hydrogenation of olefins and in many cases may result in an overall improvement in the anti-knock properties.
  • this type of treatment is conventionally applied to straight run distillates and similar materials. However, if the treatment of cracked ga'solines and similar materials under such conditions is attempted it is found that the catalyst loses activity at a rapid rate. This type of process can therefore be carried out in an intermittent manner with an oxide catalyst which is regenerated every few hours, but generally cannot be carried out continuously with a sulfide catalyst.
  • the process of the present invention in its broader aspect comprises treating cracked gasoline or similar material containing more than 0.10% sulfur in the vapor phase in the presence of between about 1 and 30 volumes of hydrogen at a pressure of at least 20 atmospheres with certain preformed metal sulfide hydrogenation-dehydrogenation catalysts while maintaining the temperature between about 850 F. and 910 F, and while maintaining the sulfur concentration in the hydrocarbon feed below 0.10%.
  • the sulfur concentration in the feed may be maintained below 0.10% by any method, but is preferably maintained below 0.10% by the methods hereinafter described.
  • the sulfur concentration in the feed is reduced to below 0.10% by treatment with a sulf-active hydrogenation catalyst at a temperature below 850 via line I. cracked gasoline fraction such for instance .as a
  • debutanized 300 F. endpoint aviation base stock fraction obtained by the catalytic cracking of a high sulfur petroleum oil with a clay-type cracking catalyst.
  • Such stocks contain considerable amounts of olefins and aromatic hydrocarbons.
  • An appreciable amount of the olefinic hydrocarbons are usually cyclic olefins such as cyclohexene.
  • the sulfur content'of such distillates is, for example, in the order of 0.18 to 0.52% and this sulfur is largely in the form of cyclic sulfur compounds such as thiophene and its homologs.
  • the amount of hydrogen recycled is, for example, between 1 and 30 volumes per volume of hydrocarbon feed.
  • the mixture of hydrogen and hydrocarbon after preheating in preheater 3 passes through a catalytic reactor 4 containing the sulfactive hydrogenation catalyst.
  • the temperaure in reactor 4 is maintained below 850 F. and preferably between about 500 F. and 750? F.
  • the pressure is maintained above about 10 atmcspheres, for example, 500-1000 p. s. i.
  • the liquid hourly space velocity is usually between about 4 and 30 and is adjusted to redu"e the sulfur to 0.10% or below, for example, 0.08%. Under such conditions the olefins in the feed are substantially unaffected or only a part of them are hydrogenated.
  • the catalyst used in reactor 4 may be any one of the various suit-active catalysts generally used by the catalytic hydrogenation of sulfur-bearing feeds.
  • Particular catalysts of this type are those comprising metals of the fifth, sixth and seventh groups of the periodic system and the iron group and zinc and copper as such and in particular in the form of their sulfides and/or oxides. These materials may be applied in various mixtures and/or if desired in con- Junction with various extender or carrier materials such as alumina, magnesia, silica, etc.
  • Particularly suitable catalysts are, for example.
  • cobalt thiomolybdate-alumina cobalt thiomolybdate-alumina, tungsten-nickel sulfide, tungsten-iron sulfide, nickel sulfide-alumina, molybdenum oxide-zinc oxide-magnesia, moybdenum oxide-chromium oxide-alumina, nickelcopper-alumina.
  • the mixture of hydrogen and partially bydrogenated product is cooled and passed to a separator 5 or other equivalent apparatus for the separation of the hydrogen recycle gas.
  • This gas contains hydrogen sulfide formed by the reduction of the sulfur compounds and is preferably cycled through a hydrogen sulfide removal system 6 of any of the conventional designs. Part of the hydrogen from which most of the hydrogen sulfide has been removed is recycled via lines I and 2. Fresh hydrogen may be supplied to the system via line l3.
  • the product from the described preliminary The liquid hourl space velocity treatment now contains 0.10% sulfur or less and a large part of the olefins.
  • This material is then subjected to a second treatment with a metal sulfide catalyst under hydrogen pressure at a temperature in the range of 850-970 1''.
  • the material is fed via line I, pump and heater I0 to reactor ll.
  • Hydrogen is supplied via line II.
  • the catalyst in reactor ll preferably comprises preformed sulfide of a metal of the iron group.
  • catalysts of this type are cobalt thiomolybdate-alumina-silica, nickel 'thiomolybdate-alumina, tungsten sulfide, nickel sulfide and tungsten sulfide-nickel sulfide.
  • the ratio or hydrogen to hydrocarbon may vary, for example, between 1:1 and 30:1.
  • the pressure is 20 atmospheres or more but insufllcient to give destructive hydrogenation. Typical pressures are, for example, between about 500 and 1000 p. s. i.
  • the liquid hourly space velocity is usually somewhat lower than in the first step and is usually in the order of 5 to 20.
  • the treatment in the second step is carried out substantially to completion; that is, the olefinic content is reduced to a small quantity. If desired, however, the treatment may be carried out at very high; space velocities to reduce the sulfur content to say only 0.005% while still leaving an appreciable amount of the oleflns unaffected. Under either of these conditions desulfurization can be obtained with an overall increase in antiknock properties and while operating in a continuous manner at a relatively high space velocity.
  • a liquid hourly space velocity in the order of may be utilized over a period of several thousand hours of continuous operation,
  • Recycle hydrogen in an amount between about 1 and 30 volumes per volume of combined feed is introduced via line 23.
  • the mixture after preheating to the desired temperature is passed to reactor 24 wherein it is contacted with the hydrogenation-dehydrogenation catalyst.
  • the temperature in reactor 24 is between 850 F. and 910 F.
  • the pressure is at least 20 atmospheres, for example, 500-1000 p. s. i.
  • the liquid hourly space velocity with respect to the mixed hydrocarbon feed is between about 4 and 30 but with respect to fresh feed is therefore considerably lower.
  • the catalyst in reactor 24 may be any one of the metal sulfide hydrogenation-dehydrogenation catalysts mentioned above for the high temperature treatment.
  • sulfides of metals of the iron group in combination with sulfldes of the metals of Group VI are particularly suitable for this application.
  • catalysts are, for example, tungsten sulfidenickel sulfide and cobalt thiomolybdate-aluminasilica.
  • This method has the disadvantage that it requires the recycling of a large amount of product, particularly if the desulfurization is carried only to a permissible maximum such as, for example, 0.03% and this necessitates separating and recycling very large amounts of hydrogen.
  • only one reactor is requiredand the method is quite advantageous in certain cases. for exampie, where the sulfur content of the charging stock is just above 0.10% and the'desulfurlzation is carried out substantially to completion.
  • the sulfur content of the feed maybe maintained below 0.10% very economically by utilizing the diluting effect of a low sulfur feed.
  • the sulfur concentration may be reduced by diluting the feed with a sulfur-free olefin polymer or a relatively sulfur-free straight run gasoline fractlon.
  • polymers, if added are introduced via line I 3 prior to the first treating step whereas straight rim gasoline, if added, is introduced via line It prior to the second treating step.
  • the use of such diluents may decrease appreciably the amount of recycling necessary. This is particularly the case if the polymer or straight run gasoline used boils outside of the range of the high sulfur feed treated. In this case it may be separated and fresh polymer or straight run feed added via line 25 to replace part or. all of the product recycle of line 22.
  • the feed is first separated into a high and a low sulfur fraction containing more and less than 0.10% sulfur by extractive distillation (see, for example, U. S: Patent 2,341,812) or by other known methods.
  • the high sulfur fraction is treated by the two step method as described above; the low sulfur fraction is recombined after the first treating step and the mixture is treated in the second treating step.
  • the feed is first separated into the high and low sulfur fractions by means not-shown.
  • the high sulfur fraction containing more than 0.10% sulfur is charged via line I and the low sulfur fraction containing less than 0.10% sulfur is introduced via line It.
  • sulfur compounds are more detrimental than other sulfur compounds in adversely effecting the activity of the catalyst when operating at temperatures above 850 F.
  • Such sulfur com- P unds may be easily removed or converted into 7 disulfides by a variety of known methods.
  • these materials are usually decomposed quite readily by materials of high surface such as active alumina, active bauxite, active clays, etc.
  • the clay type cracking catalysts (usually consisting of treated clays or synthetic blends of silica and alumina) invariably have large available surfaces and decompose mercaptan sulfur compounds quite readily.
  • the feed stocks of the type in question generally do not contain appreciable amounts of mercaptans.
  • a further improvement may be obtained by first removing the mercaptans or converting them to other less harmful sulfur compounds.
  • One method for accomplishing this is to subject the feed to a socalled solutizer treatment (such as described in U. S. Patent 2,228,295) which selectively extracts mercaptans.
  • Another method is to pass the distillate over bauxite, over active clay, or over a metal oxide catalyst such as Luxmass, iron oxide, molybdenum oxide or the like which tends to decompose mercaptans andbecome converted to the corresponding metal sulfide.
  • the metal sulfide so formed may then be used in the described hydrogenation step or steps or it may be regenerated to form the oxide.
  • Still another method is to pass the distillate in the presence of a small regulated amount of an oxidant such as air or steam over clay or the like to oxidize the mercaptans to the disulfldes. In some cases the oxidation may be carried out in the wet way by.
  • the feed containing mercaptans and more than 0.1% sulfur entering via line is first subjected to a doctor treatment to oxidize the mercaptans.
  • the feed then passes via line H to a treating system wherein it is treated as described in connection with Figure I.
  • a catalyst frequently recommended for catalytic desulfurization is molybdenum sulfide.
  • the superior life of catalysts of the type herein specifled (containing a sulfide of a metal of the iron group) as compared tomolybdenum sulfide is illustrated by the following results:
  • a good and typical molybdenum sulfide catalyst was used for the hydrogenation-desulfurization of a third cut cracked gasoline having the following inspection conditions.
  • the catalyst activity decline rate (expressed in per cent increase in sulfur retention per 1000 bbls. of feed treated per bbl. of catalyst) in the case of the molybdenum sulfide catalyst was 13.0; that for the nickel sulfidetungsten sulfide catalyst was less than 0.2.
  • a nickel sulfide-tungsten sulfide catalyst was used for the hydrogenation-desulfurization of a catalytically cracked gasoline having the following inspection data:
  • Boiling range F 110-330 Gravity A. P. I 52.0 Bromine number 45 Sulfur per cent 0.14 Aromatics per cent by volume 32.5
  • the life of the catalyst, as expressed above was more than 1250 hours.
  • the preliminary reduction of the sulfur content to below 0.10% may be effected by dilution with desulfurized product. Also, as illustrated by other results given, such a preliminary sulfur reduc tion may be carried out with the same or a different catalyst without loss of efliciency, providing that the treatment is carried out at temperatures below 850 Rand preferably below about 810 F.
  • operation at these temperatures affords a lower hydrogen consumption, (due to the fact that additional aromatics and hydrogen are formed by the dehydrogenation of naphthenic and cyclic olefin components in the field and/or to the fact that somewhat less olefins are hydrogenated). Also operation at these temperatures generally affords products of better anti-knock characteristics (probably due to avoidance of hydrogenation of aromatics and/or to production of aromatics).
  • aromatic hydrocarbons in the feed are not hydrogenated as they are prone to do when operating at lower temperatures, but additional aromatic hydrocarbons may be produced in the process by dehydrogenation of naphthenes and cyclic. olefins (and possibly also by dehydrocyclization). These dehydrogenation reactions are highly endothermic.
  • the hydrogenation of sulfur compounds and oleflns is exothermic. By limiting the treatment in the first step to bring the sulfur concentration down only to just below 0.10% the -major amount of the olefins remains unchanged. Most of these oleflns are then hydrogenated in the second (high temperature) step and serve to supply the heat for the endothermic dehydrogenation reaco tions.
  • a process for the improvement of cracked gasolines and similar hydrocarbon distillates containing sulfur compounds equivalent to more than 0.10% sulfur which comprises selectively extracting mercaptans from said material, continuously passing the demercaptanized material in the vapor phase in admixture with from about 1 to about 30 volumes of hydrogen through a reaction zone containing a hydrogenation-dehydrogenation sulfide of a metal of the iron group at a temperature between about 850 F. and 910 F.

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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)
US569234A 1944-12-21 1944-12-21 Catalytic treatment of sulfurbearing hydrocarbon distillates Expired - Lifetime US2431920A (en)

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FR918705D FR918705A (fr) 1944-12-21 1945-12-11 Procédé de traitement catalytique des produits de distillation des hydrocarbures contenant du soufre

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Cited By (23)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2516877A (en) * 1946-09-27 1950-08-01 Gulf Research Development Co Desulfurization of heavy petroleum hydrocarbons
US2516876A (en) * 1946-09-27 1950-08-01 Gulf Research Development Co Desulfurization of light petroleum hydrocarbons
US2538248A (en) * 1947-11-28 1951-01-16 Universal Oil Prod Co Isomerization of olefins
US2574445A (en) * 1947-08-26 1951-11-06 Anglo Iranian Oil Co Ltd Catalytic desulfurization of kerosene and white spirits
US2608521A (en) * 1948-01-06 1952-08-26 Shell Dev Process for refining carbonaceous material
US2656302A (en) * 1949-09-22 1953-10-20 Anglo Iranian Oil Co Ltd Catalytic desulfurization of petroleum hydrocarbons
DE927947C (de) * 1949-12-29 1955-05-20 Anglo Iranian Oil Co Ltd Verfahren zur katalytischen Entschwefelung von hoehersiedenden naphthenhaltigen Erdoeldestillaten
DE950590C (de) * 1948-06-01 1956-10-11 British Petroleum Co Verfahren zur katalytischen Entschwefelung naphthenhaltiger, ueber 375íÒ siedender Erdoeldestillate
US2769754A (en) * 1954-05-03 1956-11-06 Exxon Research Engineering Co Process for hydrodesulfurization of coker products
DE966995C (de) * 1947-12-16 1957-09-26 British Petroleum Co Verfahren zur katalytischen Entschwefelung naphthenhaltiger Erdoeldestillate
US2833698A (en) * 1954-04-27 1958-05-06 Kellogg M W Co Hydrocarbon hydroconversion where petroleum fractions are treated in parallel reactions while passing hydrogen serially through the reactors
US2833697A (en) * 1953-10-23 1958-05-06 Basf Ag Desulfurization of crude oils by catalytic high-pressure hydrogenation
US2847361A (en) * 1954-04-12 1958-08-12 Standard Oil Co Separation of hydrogen sulfide and hydrocarbons from hydrogen streams
US2901417A (en) * 1954-05-17 1959-08-25 Exxon Research Engineering Co Hydrodesulfurization of a coked hydrocarbon stream comprising gasoline constituents and gas oil constituents
US2906694A (en) * 1953-08-19 1959-09-29 Exxon Research Engineering Co Integrated hydrofining process
US2938857A (en) * 1956-11-08 1960-05-31 Sun Oil Co Split hydrorefining of feed to catalytic cracking operation
US2984614A (en) * 1957-09-06 1961-05-16 Socony Mobil Oil Co Inc Treatment of distillate feed
DE977260C (de) * 1953-08-19 1965-08-12 Exxon Research Engineering Co Verfahren zur Gewinnung eines hochwertigen Benzins und eines stabilen Gemischheizoeles aus Rohoel
DE977579C (de) * 1954-12-12 1967-05-03 Exxon Research Engineering Co Verfahren zur Verbesserung des Verkokungstestes unbehandelter und/oder gespaltener Heizoele
US3365374A (en) * 1967-06-07 1968-01-23 Chevron Res H2s recovery by absorption and plural distillation
EP1746144A1 (fr) 2005-07-18 2007-01-24 Institut Français du Pétrole Nouveau procédé de désulfuration d'essences oléfiniques permettant de limiter la teneur en mercaptans
CN102465025A (zh) * 2010-11-05 2012-05-23 中国石油化工股份有限公司 一种劣质汽油加工方法
US10822555B2 (en) 2015-04-15 2020-11-03 IFP Energies Nouvelles Method for sweetening an olefinic petrol of sulphide-type compounds

Citations (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB418926A (en) * 1932-07-26 1934-11-02 Ig Farbenindustrie Ag Improvements in the production of non-knocking benzines
US2025255A (en) * 1934-02-07 1935-12-24 Shell Dev Method of treating cracked oil distillates
US2167602A (en) * 1936-10-06 1939-07-25 Phillips Petroleum Co Treatment of hydrocarbon oils
US2183591A (en) * 1939-12-19 Peocess for treatment of hydro
US2232909A (en) * 1939-06-20 1941-02-25 Standard Ig Co Hydrogenation process
US2273299A (en) * 1938-10-08 1942-02-17 Albert C Travis Treatment of hydrocarbons
US2273298A (en) * 1938-09-23 1942-02-17 Albert Chester Travis Treatment of hydrocarbons
US2316092A (en) * 1942-09-19 1943-04-06 Socony Vacuum Oil Co Inc Method of treating oils
US2315530A (en) * 1941-07-31 1943-04-06 Socony Vacuum Oil Co Inc Method of sweetening oils
US2325034A (en) * 1940-08-20 1943-07-27 Union Oil Co Method of desulphurizing petroleum fractions
US2370707A (en) * 1942-11-02 1945-03-06 Shell Dev Treatment of hydrocarbons

Patent Citations (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2183591A (en) * 1939-12-19 Peocess for treatment of hydro
GB418926A (en) * 1932-07-26 1934-11-02 Ig Farbenindustrie Ag Improvements in the production of non-knocking benzines
US2025255A (en) * 1934-02-07 1935-12-24 Shell Dev Method of treating cracked oil distillates
US2167602A (en) * 1936-10-06 1939-07-25 Phillips Petroleum Co Treatment of hydrocarbon oils
US2273298A (en) * 1938-09-23 1942-02-17 Albert Chester Travis Treatment of hydrocarbons
US2273299A (en) * 1938-10-08 1942-02-17 Albert C Travis Treatment of hydrocarbons
US2232909A (en) * 1939-06-20 1941-02-25 Standard Ig Co Hydrogenation process
US2325034A (en) * 1940-08-20 1943-07-27 Union Oil Co Method of desulphurizing petroleum fractions
US2315530A (en) * 1941-07-31 1943-04-06 Socony Vacuum Oil Co Inc Method of sweetening oils
US2316092A (en) * 1942-09-19 1943-04-06 Socony Vacuum Oil Co Inc Method of treating oils
US2370707A (en) * 1942-11-02 1945-03-06 Shell Dev Treatment of hydrocarbons

Cited By (25)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US2516877A (en) * 1946-09-27 1950-08-01 Gulf Research Development Co Desulfurization of heavy petroleum hydrocarbons
US2516876A (en) * 1946-09-27 1950-08-01 Gulf Research Development Co Desulfurization of light petroleum hydrocarbons
US2574445A (en) * 1947-08-26 1951-11-06 Anglo Iranian Oil Co Ltd Catalytic desulfurization of kerosene and white spirits
US2538248A (en) * 1947-11-28 1951-01-16 Universal Oil Prod Co Isomerization of olefins
DE966995C (de) * 1947-12-16 1957-09-26 British Petroleum Co Verfahren zur katalytischen Entschwefelung naphthenhaltiger Erdoeldestillate
US2608521A (en) * 1948-01-06 1952-08-26 Shell Dev Process for refining carbonaceous material
DE950590C (de) * 1948-06-01 1956-10-11 British Petroleum Co Verfahren zur katalytischen Entschwefelung naphthenhaltiger, ueber 375íÒ siedender Erdoeldestillate
US2656302A (en) * 1949-09-22 1953-10-20 Anglo Iranian Oil Co Ltd Catalytic desulfurization of petroleum hydrocarbons
DE927947C (de) * 1949-12-29 1955-05-20 Anglo Iranian Oil Co Ltd Verfahren zur katalytischen Entschwefelung von hoehersiedenden naphthenhaltigen Erdoeldestillaten
DE977260C (de) * 1953-08-19 1965-08-12 Exxon Research Engineering Co Verfahren zur Gewinnung eines hochwertigen Benzins und eines stabilen Gemischheizoeles aus Rohoel
US2906694A (en) * 1953-08-19 1959-09-29 Exxon Research Engineering Co Integrated hydrofining process
US2833697A (en) * 1953-10-23 1958-05-06 Basf Ag Desulfurization of crude oils by catalytic high-pressure hydrogenation
US2847361A (en) * 1954-04-12 1958-08-12 Standard Oil Co Separation of hydrogen sulfide and hydrocarbons from hydrogen streams
US2833698A (en) * 1954-04-27 1958-05-06 Kellogg M W Co Hydrocarbon hydroconversion where petroleum fractions are treated in parallel reactions while passing hydrogen serially through the reactors
US2769754A (en) * 1954-05-03 1956-11-06 Exxon Research Engineering Co Process for hydrodesulfurization of coker products
US2901417A (en) * 1954-05-17 1959-08-25 Exxon Research Engineering Co Hydrodesulfurization of a coked hydrocarbon stream comprising gasoline constituents and gas oil constituents
DE977579C (de) * 1954-12-12 1967-05-03 Exxon Research Engineering Co Verfahren zur Verbesserung des Verkokungstestes unbehandelter und/oder gespaltener Heizoele
US2938857A (en) * 1956-11-08 1960-05-31 Sun Oil Co Split hydrorefining of feed to catalytic cracking operation
US2984614A (en) * 1957-09-06 1961-05-16 Socony Mobil Oil Co Inc Treatment of distillate feed
US3365374A (en) * 1967-06-07 1968-01-23 Chevron Res H2s recovery by absorption and plural distillation
EP1746144A1 (fr) 2005-07-18 2007-01-24 Institut Français du Pétrole Nouveau procédé de désulfuration d'essences oléfiniques permettant de limiter la teneur en mercaptans
JP2007023285A (ja) * 2005-07-18 2007-02-01 Inst Fr Petrole チオール含有量を制限するためにオレフィンガソリンを脱硫するための新規な方法
CN102465025A (zh) * 2010-11-05 2012-05-23 中国石油化工股份有限公司 一种劣质汽油加工方法
CN102465025B (zh) * 2010-11-05 2014-05-21 中国石油化工股份有限公司 一种劣质汽油加工方法
US10822555B2 (en) 2015-04-15 2020-11-03 IFP Energies Nouvelles Method for sweetening an olefinic petrol of sulphide-type compounds

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