CN1448481A - Method for production of low sulfur and thiol content hydrocarbon - Google Patents
Method for production of low sulfur and thiol content hydrocarbon Download PDFInfo
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- CN1448481A CN1448481A CN03128651.8A CN03128651A CN1448481A CN 1448481 A CN1448481 A CN 1448481A CN 03128651 A CN03128651 A CN 03128651A CN 1448481 A CN1448481 A CN 1448481A
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- desulfurization
- gasoline
- hydrogen
- sulphur
- effluent
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- 229930195733 hydrocarbon Natural products 0.000 title claims abstract description 16
- 239000004215 Carbon black (E152) Substances 0.000 title claims abstract description 15
- 150000002430 hydrocarbons Chemical class 0.000 title claims abstract description 14
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 title description 67
- 229910052717 sulfur Inorganic materials 0.000 title description 14
- 239000011593 sulfur Substances 0.000 title description 13
- 238000004519 manufacturing process Methods 0.000 title description 4
- 125000003396 thiol group Chemical class [H]S* 0.000 title 1
- 238000006477 desulfuration reaction Methods 0.000 claims abstract description 86
- 230000023556 desulfurization Effects 0.000 claims abstract description 85
- 238000000034 method Methods 0.000 claims abstract description 71
- 239000003054 catalyst Substances 0.000 claims abstract description 31
- 229910052739 hydrogen Inorganic materials 0.000 claims abstract description 29
- 239000001257 hydrogen Substances 0.000 claims abstract description 28
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 claims abstract description 25
- 230000008569 process Effects 0.000 claims abstract description 18
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 claims abstract description 16
- 238000000926 separation method Methods 0.000 claims abstract description 9
- 150000001875 compounds Chemical class 0.000 claims abstract description 8
- 229910000037 hydrogen sulfide Inorganic materials 0.000 claims abstract description 8
- 150000003464 sulfur compounds Chemical class 0.000 claims abstract 5
- 239000000463 material Substances 0.000 claims description 25
- 238000005984 hydrogenation reaction Methods 0.000 claims description 11
- PXHVJJICTQNCMI-UHFFFAOYSA-N Nickel Chemical compound [Ni] PXHVJJICTQNCMI-UHFFFAOYSA-N 0.000 claims description 10
- 239000007788 liquid Substances 0.000 claims description 10
- ZOKXTWBITQBERF-UHFFFAOYSA-N Molybdenum Chemical compound [Mo] ZOKXTWBITQBERF-UHFFFAOYSA-N 0.000 claims description 7
- 150000001993 dienes Chemical class 0.000 claims description 7
- 229910052750 molybdenum Inorganic materials 0.000 claims description 7
- 239000011733 molybdenum Substances 0.000 claims description 7
- 229910052759 nickel Inorganic materials 0.000 claims description 6
- 238000004523 catalytic cracking Methods 0.000 claims description 5
- 229910017052 cobalt Inorganic materials 0.000 claims description 5
- 239000010941 cobalt Substances 0.000 claims description 5
- GUTLYIVDDKVIGB-UHFFFAOYSA-N cobalt atom Chemical compound [Co] GUTLYIVDDKVIGB-UHFFFAOYSA-N 0.000 claims description 5
- WFKWXMTUELFFGS-UHFFFAOYSA-N tungsten Chemical compound [W] WFKWXMTUELFFGS-UHFFFAOYSA-N 0.000 claims description 4
- 229910052721 tungsten Inorganic materials 0.000 claims description 4
- 239000010937 tungsten Substances 0.000 claims description 4
- 238000004939 coking Methods 0.000 claims description 2
- 238000004230 steam cracking Methods 0.000 claims description 2
- 230000000737 periodic effect Effects 0.000 claims 4
- 239000005864 Sulphur Substances 0.000 description 59
- 150000001336 alkenes Chemical class 0.000 description 28
- LSDPWZHWYPCBBB-UHFFFAOYSA-N Methanethiol Chemical compound SC LSDPWZHWYPCBBB-UHFFFAOYSA-N 0.000 description 14
- JRZJOMJEPLMPRA-UHFFFAOYSA-N olefin Natural products CCCCCCCC=C JRZJOMJEPLMPRA-UHFFFAOYSA-N 0.000 description 14
- TVMXDCGIABBOFY-UHFFFAOYSA-N octane Chemical compound CCCCCCCC TVMXDCGIABBOFY-UHFFFAOYSA-N 0.000 description 12
- 230000002829 reductive effect Effects 0.000 description 11
- 229910052751 metal Inorganic materials 0.000 description 9
- 239000002184 metal Substances 0.000 description 9
- -1 sulphur compound Chemical class 0.000 description 9
- FGUUSXIOTUKUDN-IBGZPJMESA-N C1(=CC=CC=C1)N1C2=C(NC([C@H](C1)NC=1OC(=NN=1)C1=CC=CC=C1)=O)C=CC=C2 Chemical compound C1(=CC=CC=C1)N1C2=C(NC([C@H](C1)NC=1OC(=NN=1)C1=CC=CC=C1)=O)C=CC=C2 FGUUSXIOTUKUDN-IBGZPJMESA-N 0.000 description 8
- 238000009835 boiling Methods 0.000 description 7
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 6
- YTPLMLYBLZKORZ-UHFFFAOYSA-N Thiophene Chemical compound C=1C=CSC=1 YTPLMLYBLZKORZ-UHFFFAOYSA-N 0.000 description 6
- PNEYBMLMFCGWSK-UHFFFAOYSA-N aluminium oxide Inorganic materials [O-2].[O-2].[O-2].[Al+3].[Al+3] PNEYBMLMFCGWSK-UHFFFAOYSA-N 0.000 description 6
- 238000006243 chemical reaction Methods 0.000 description 6
- 235000009508 confectionery Nutrition 0.000 description 6
- 230000000694 effects Effects 0.000 description 6
- 239000007789 gas Substances 0.000 description 6
- 229910052799 carbon Inorganic materials 0.000 description 5
- 239000000203 mixture Substances 0.000 description 5
- TWNQGVIAIRXVLR-UHFFFAOYSA-N oxo(oxoalumanyloxy)alumane Chemical compound O=[Al]O[Al]=O TWNQGVIAIRXVLR-UHFFFAOYSA-N 0.000 description 5
- 239000012071 phase Substances 0.000 description 5
- 239000000446 fuel Substances 0.000 description 4
- 229910021472 group 8 element Inorganic materials 0.000 description 4
- 230000036571 hydration Effects 0.000 description 4
- 238000006703 hydration reaction Methods 0.000 description 4
- 239000003208 petroleum Substances 0.000 description 4
- 238000000197 pyrolysis Methods 0.000 description 4
- UCKMPCXJQFINFW-UHFFFAOYSA-N Sulphide Chemical compound [S-2] UCKMPCXJQFINFW-UHFFFAOYSA-N 0.000 description 3
- 238000001354 calcination Methods 0.000 description 3
- 150000002431 hydrogen Chemical class 0.000 description 3
- 230000003647 oxidation Effects 0.000 description 3
- 238000007254 oxidation reaction Methods 0.000 description 3
- 238000012545 processing Methods 0.000 description 3
- 230000009467 reduction Effects 0.000 description 3
- 229920006395 saturated elastomer Polymers 0.000 description 3
- 239000000377 silicon dioxide Substances 0.000 description 3
- 229960001866 silicon dioxide Drugs 0.000 description 3
- 235000012239 silicon dioxide Nutrition 0.000 description 3
- 229930192474 thiophene Natural products 0.000 description 3
- QPLDLSVMHZLSFG-UHFFFAOYSA-N Copper oxide Chemical compound [Cu]=O QPLDLSVMHZLSFG-UHFFFAOYSA-N 0.000 description 2
- LFQSCWFLJHTTHZ-UHFFFAOYSA-N Ethanol Chemical compound CCO LFQSCWFLJHTTHZ-UHFFFAOYSA-N 0.000 description 2
- IMNFDUFMRHMDMM-UHFFFAOYSA-N N-Heptane Chemical compound CCCCCCC IMNFDUFMRHMDMM-UHFFFAOYSA-N 0.000 description 2
- KDLHZDBZIXYQEI-UHFFFAOYSA-N Palladium Chemical compound [Pd] KDLHZDBZIXYQEI-UHFFFAOYSA-N 0.000 description 2
- GWEVSGVZZGPLCZ-UHFFFAOYSA-N Titan oxide Chemical compound O=[Ti]=O GWEVSGVZZGPLCZ-UHFFFAOYSA-N 0.000 description 2
- XLOMVQKBTHCTTD-UHFFFAOYSA-N Zinc monoxide Chemical compound [Zn]=O XLOMVQKBTHCTTD-UHFFFAOYSA-N 0.000 description 2
- 230000004913 activation Effects 0.000 description 2
- 239000003463 adsorbent Substances 0.000 description 2
- 230000008901 benefit Effects 0.000 description 2
- 150000001721 carbon Chemical group 0.000 description 2
- 238000007233 catalytic pyrolysis Methods 0.000 description 2
- 238000005336 cracking Methods 0.000 description 2
- 238000004821 distillation Methods 0.000 description 2
- 230000002349 favourable effect Effects 0.000 description 2
- 238000006317 isomerization reaction Methods 0.000 description 2
- 239000011159 matrix material Substances 0.000 description 2
- 229910044991 metal oxide Inorganic materials 0.000 description 2
- 150000004706 metal oxides Chemical class 0.000 description 2
- BASFCYQUMIYNBI-UHFFFAOYSA-N platinum Chemical compound [Pt] BASFCYQUMIYNBI-UHFFFAOYSA-N 0.000 description 2
- 238000002203 pretreatment Methods 0.000 description 2
- 238000005215 recombination Methods 0.000 description 2
- 230000006798 recombination Effects 0.000 description 2
- 230000001105 regulatory effect Effects 0.000 description 2
- 230000004044 response Effects 0.000 description 2
- 239000007787 solid Substances 0.000 description 2
- 230000007704 transition Effects 0.000 description 2
- UHOVQNZJYSORNB-UHFFFAOYSA-N Benzene Chemical compound C1=CC=CC=C1 UHOVQNZJYSORNB-UHFFFAOYSA-N 0.000 description 1
- WKBOTKDWSSQWDR-UHFFFAOYSA-N Bromine atom Chemical compound [Br] WKBOTKDWSSQWDR-UHFFFAOYSA-N 0.000 description 1
- 238000010521 absorption reaction Methods 0.000 description 1
- 238000007259 addition reaction Methods 0.000 description 1
- 150000001412 amines Chemical class 0.000 description 1
- QGAVSDVURUSLQK-UHFFFAOYSA-N ammonium heptamolybdate Chemical group N.N.N.N.N.N.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.O.[Mo].[Mo].[Mo].[Mo].[Mo].[Mo].[Mo] QGAVSDVURUSLQK-UHFFFAOYSA-N 0.000 description 1
- 238000004458 analytical method Methods 0.000 description 1
- 239000007864 aqueous solution Substances 0.000 description 1
- 238000005844 autocatalytic reaction Methods 0.000 description 1
- GDTBXPJZTBHREO-UHFFFAOYSA-N bromine Substances BrBr GDTBXPJZTBHREO-UHFFFAOYSA-N 0.000 description 1
- 229910052794 bromium Inorganic materials 0.000 description 1
- 238000004364 calculation method Methods 0.000 description 1
- 125000004432 carbon atom Chemical group C* 0.000 description 1
- 238000006555 catalytic reaction Methods 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 238000001816 cooling Methods 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 239000010779 crude oil Substances 0.000 description 1
- 229960004643 cupric oxide Drugs 0.000 description 1
- 238000000354 decomposition reaction Methods 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- HRKQOINLCJTGBK-UHFFFAOYSA-N dihydroxidosulfur Chemical compound OSO HRKQOINLCJTGBK-UHFFFAOYSA-N 0.000 description 1
- WQOXQRCZOLPYPM-UHFFFAOYSA-N dimethyl disulfide Chemical group CSSC WQOXQRCZOLPYPM-UHFFFAOYSA-N 0.000 description 1
- 238000007598 dipping method Methods 0.000 description 1
- 238000001035 drying Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 230000002779 inactivation Effects 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 238000009434 installation Methods 0.000 description 1
- 239000007791 liquid phase Substances 0.000 description 1
- 239000000395 magnesium oxide Substances 0.000 description 1
- CPLXHLVBOLITMK-UHFFFAOYSA-N magnesium oxide Inorganic materials [Mg]=O CPLXHLVBOLITMK-UHFFFAOYSA-N 0.000 description 1
- AXZKOIWUVFPNLO-UHFFFAOYSA-N magnesium;oxygen(2-) Chemical compound [O-2].[Mg+2] AXZKOIWUVFPNLO-UHFFFAOYSA-N 0.000 description 1
- 229910000476 molybdenum oxide Inorganic materials 0.000 description 1
- 229920001206 natural gum Polymers 0.000 description 1
- 238000011017 operating method Methods 0.000 description 1
- 238000005457 optimization Methods 0.000 description 1
- PQQKPALAQIIWST-UHFFFAOYSA-N oxomolybdenum Chemical compound [Mo]=O PQQKPALAQIIWST-UHFFFAOYSA-N 0.000 description 1
- 229910052763 palladium Inorganic materials 0.000 description 1
- 229910052697 platinum Inorganic materials 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 239000002243 precursor Substances 0.000 description 1
- 238000002360 preparation method Methods 0.000 description 1
- 238000007493 shaping process Methods 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 150000003463 sulfur Chemical class 0.000 description 1
- XTQHKBHJIVJGKJ-UHFFFAOYSA-N sulfur monoxide Chemical compound S=O XTQHKBHJIVJGKJ-UHFFFAOYSA-N 0.000 description 1
- 238000007669 thermal treatment Methods 0.000 description 1
- 239000004408 titanium dioxide Substances 0.000 description 1
- 230000009466 transformation Effects 0.000 description 1
- 238000005406 washing Methods 0.000 description 1
- 239000011787 zinc oxide Substances 0.000 description 1
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
Landscapes
- Chemical & Material Sciences (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Engineering & Computer Science (AREA)
- Chemical Kinetics & Catalysis (AREA)
- General Chemical & Material Sciences (AREA)
- Organic Chemistry (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
- Catalysts (AREA)
Abstract
含有硫化合物和烯烃化合物的含烃馏分脱硫方法，该方法包括至少下述的相继步骤：在导致所述馏分脱硫率严格地高于90％的条件下，在氢和加氢脱硫催化剂存在下第一次脱硫；从来自第一次脱硫的流出物中分离主要部分的硫化氢；在氢和加氢脱硫催化剂存在下，在导致所述流出物的脱硫率低于第一次脱硫的脱硫率的条件下，来自分离步骤和除去硫化氢的流出物的第二次脱硫。Process for the desulfurization of hydrocarbon-containing fractions containing sulfur compounds and olefinic compounds, the process comprising at least the following sequential steps: in the presence of hydrogen and a hydrodesulfurization catalyst, under conditions resulting in the desulfurization of said fractions strictly higher than 90%. Primary desulfurization; separation of a major portion of hydrogen sulfide from an effluent from the first desulfurization; in the presence of hydrogen and a hydrodesulfurization catalyst, at a rate that results in said effluent being less desulfurized than the desulfurization rate of the first desulfurization conditions, a second desulfurization of the effluent from the separation step and removal of hydrogen sulfide.
Description
Technical field
The present invention relates to a kind of production method of low sulfur content hydrocarbon.This hydrocarbon-fraction contains and generally is higher than 5 weight %, often is higher than 10 weight % olefin fractions.This method is because of being reduced to low-down level with the sulphur and the mercaptans content of described gasoline fraction, also do not reduce gasoline yield simultaneously, the minimizing of octane value also can be reduced to minimumly in described procedure, so this method especially can make the whole gasoline fraction increment that contains sulphur.When pending gasoline is that sulphur content is higher than 500ppm by weight, or even be higher than 1000ppm, when especially being higher than the catalytic cracking gasoline of 2000ppm, the sulphur content of being studied in the sweet gasoline is lower than 50ppm, even be lower than 20ppm or especially during 10ppm, the present invention has its special application.
Background technology
Automobile fuel technological standard in the future should be taken into account the sulphur content that is reduced in greatly in these fuel, especially the sulphur content in the gasoline.This reduction is used for restriction especially at automobile emission gas sulphur oxide content.At present, the technological standard of sulphur content is about 150ppm weight, future these years in, after carrying out the transition to 30ppm weight, its content reaches and is lower than 10ppm.Therefore the technological standard of sulphur content develops in these fuel needs the new deep desulfurization of gasoline method of development.
The basic source of sulphur is so-called pyrolysis gasoline in the gasoline matrix, and this gasoline fraction is in principle from the catalystic pyrolysis of crude oil atmospheric distillation or vacuum distilling residue.Gasoline fraction from catalytic pyrolysis on average accounts for gasoline matrix 40%, and this cut in fact provides sulphur more than 90% for gasoline.Therefore, produce the desulfurized step that the few gasoline of sulfur-bearing needs a catalytic cracking gasoline.In the method for so-called hydrogenating desulfurization, carry out this desulfurization by sulfocompound that contains in one or more described gasoline and the contact procedure that is rich in the gas of hydrogen usually.
In addition, the octane value of gasoline and its olefin(e) centent are very closely related like this.Therefore keep these gasoline octane ratings need limit the reaction that conversion of olefines becomes paraffinic hydrocarbons, these reactions are hydrodesulfurizationprocess process institute inherent.
In addition, these gasoline have corrodibility because of there being mercaptan.In order to limit gasoline corrosion, generally mercaptans content need be reduced to greatly and be lower than 10ppm at least, be lower than the value of 5ppm ideally.The mercaptan of measuring in sweet gasoline is so-called recombination mercaptan, the hydrogen sulfide (H that produces in the promptly comfortable desulfurized step
2S) with gasoline in the mercaptan of addition reaction of the alkene that exists.Removing the common terms of settlement that adopts of these mercaptan is to make the olefin hydrogenation that exists in the gasoline.But, because the reason of having described, this hydrogenization can cause serious loss of octane number to catalytic cracking gasoline.
People once proposed many terms of settlement and come selectivity to remove sulfocompound in the gasoline, limited these undesirable olefin hydrogenation reactions, and those skilled in the art estimate this hydrogenation with the alkene saturation exponent form at reactor outlet.In these methods, can select gasoline in one or two tandem reactor, to handle, no intermediate section is from H
2These methods of S.These methods can partly solve octane value and the mercaptan problem that sulphur content generally is no more than the 1000ppm material, and are very low to the desulfurization degree that these materials try hard to reach, and typically are lower than 90%.
In order to reach sulphur content at last less than 50ppm, even less than 20ppm or 10ppm especially, the gasoline that sulphur is rich in processing (promptly contains more than the 1000ppm, even the above sulphur of 2000ppm), randomly and preferably may need to implement a kind of method, this method is included in hydrogenating desulfurization effect and the middle H that generates that removes at least two serial hydrogenation desulphurization reactors in first hydrodesulfurisationstep step process
2S.This class scheme optimization ground is used to reach high desulfurization rate, and for example 99% desulfurization degree makes the gasoline of the about 2000ppm of sulphur concentration reach the about 10ppm of sulphur concentration.
For example, patent EP 0 755 995 has proposed a kind of scheme, and this scheme is removed H by at least two hydrodesulfurisationstep step and one between two hydrodesulphurisatioreactors reactors
2The step of S is formed.In each step hydrogenating desulfurization rate should be 60-90%.But a kind of like this method can not be expected that technical scale reaches and be higher than 99% desulfurization degree.In order to reach more deep desulfuration, obviously be necessary to increase at least one replenish step, so just seriously limited the economic incentive of this method.
Patent US 6 231 753 has proposed to adopt a kind of scheme to handle the gasoline of high sulfur-bearing, and this scheme comprises also that two hydrodesulfurisationstep step and centre are removed and generates H
2The step of S.These operational conditions are to make the gasoline desulfur rate of second hydrodesulfurisationstep step and temperature be higher than first step.
Summary of the invention
Usually, the present invention relates to a kind of novel method, this method comprises that two hydrodesulfurisationstep step and a centre remove H
2The step of S, this method can be simultaneously:
-according to these countries, reach the technological standard of motor benzine in the future, i.e. the about 30ppm of sulphur content, even 10ppm,
Olefin hydrogenation process in the described method of-control,
The loss of octane number that-restriction is relevant with hydrodesulfurizationprocess process,
-reduce mercaptans content so that in sweet gasoline certain sulphur and olefin(e) centent.
More properly, the present invention relates to a kind of hydrocarbon cut sulfur method that contains sulphur compound and olefin(e) compound, this method comprises following at least sequential step:
-causing described cut desulfurization degree strictly to be higher than under 90% the condition, desulfurization for the first time in the presence of hydrogen and Hydrobon catalyst,
-from hydrogen sulfide (H from separation major portion the effluent of the desulfurization first time
2S),
-in the presence of hydrogen and Hydrobon catalyst, be lower than at the desulfurization degree that causes described effluent under the condition of desulfurization degree of desulfurization for the first time, from the separating step and the desulfurization second time of removing the effluent of hydrogen sulfide.
Therefore, this sulfur method proposes a kind of high desulfurization rate that reaches, and typically is higher than 95%, more properly is higher than 99%, simultaneously the terms of settlement that limits the loss of octane that is produced by hydrogenated olefins and form recombination mercaptan.Produce low-sulfur and low thioalcohol and high-octane gasoline thus.
The present invention relates to a kind of sulfur method that contains the hydrocarbon cut of sulphur compound and olefin(e) compound, this method comprises following at least sequential step:
-causing described cut desulfurization degree strictly to be higher than under 90% the condition, desulfurization for the first time in the presence of hydrogen and Hydrobon catalyst,
-from hydrogen sulfide (H from separation major portion the effluent of the desulfurization first time
2S),
-in the presence of hydrogen and Hydrobon catalyst, be lower than under the condition of desulfurization degree of desulfurization for the first time the desulfurization second time of removing the effluent of hydrogen sulfide from separating step at the desulfurization degree that causes described effluent.
In the method for the invention, preferably at least a Hydrobon catalyst contains at least a period of element sorted table group VIII element, and more preferably at least a catalyzer also contains at least a period of element sorted table group vib element.
Most preferably, described Hydrobon catalyst contains at least a period of element sorted table group VIII element and at least a period of element sorted table group vib element that is selected from molybdenum and tungsten that is selected from nickel and cobalt.
Preferably, the desulfurization first time of the inventive method is to carry out under the following condition: temperature 250-350 ℃, pressure 1-3 MPa, liquid hourly space speed 1-10 hour
-1, and H
2/ HC than 50-500 liter/liter, preferably, desulfurization for the second time is to carry out under the following condition: temperature 200-300 ℃, pressure 1-3 MPa, liquid hourly space speed 1-10 hour
-1, and H
2/ HC than 50-500 liter/liter.
Preferably, the desulfurization degree of desulfurization for the second time is that strictness is higher than 80%, and more preferably, the difference of the desulfurization degree of desulfurization for the first time and the desulfurization degree of desulfurization for the second time is one of absolute value percentage at least.Such difference can reach by following method especially: by for the first time and the temperature head between the desulfurization second time and/or per hour volumetric velocity is poor, and/or by first with second hydrodesulfurisationstep step in the different catalytically active of use catalyzer, for example according to the composition of these catalyzer or preparation method's difference.
Method of the present invention randomly can also be included in the selective hydration replenish step that contains diolefine in the hydrocarbon cut, and described step was carried out before the desulfurization first time.More preferably, this method can also comprise the replenish step that light sulfocompound increases the weight of, and described step was carried out before the desulfurization first time, can also comprise that most preferably described cut is separated at least one replenish step of at least two kinds of cuts, wherein:
-contain the very lighting end of small portion sulfocompound,
-contain the last running of major portion sulfocompound, then, described at least last running can be handled according to first desulfurized step.
Method of the present invention preferably is applicable to the material of the gasoline fraction of Tathagata autocatalysis cracking or coking of hydrocarbonaceous heavy burder or steam cracking.
Will be better understood the present invention by the embodiment of the present invention of reading following pure illustrative and provide without limitation.
Embodiment
According to following preferred but non-imposed embodiment of the present invention, material to be desulfurization is in advance in selective hydration diolefine (step a) and add (the non-imposed processing in the reactor chain of step b) of heavy and light sulfocompound.Pretreated like this material redistillation is fractionated at least two kinds of cuts (step c): the heavy petrol of the petroleum naphtha of poor sulphur rich olefins and the poor alkene of rich sulphur.Generally contain sulphur below the 50ppm from the lighting end of three preceding step, the following sulphur of 20ppm preferably, the following sulphur of 10ppm most preferably, this cut did not generally need to carry out last processing before adding as the gasoline base-material.Last running from three preceding step has concentrated most of sulphur, can handle according to purpose method of the present invention.The advantage of this preferred implementation is to make loss of octane minimum, because hydrogenant has the light olefin of 5 carbon atoms not deliver to hydrodesulfurizationsection section easily.
Usually, these pre-treatment step a), b) and experiment condition c) as follows:
1) selective hydration effect (step a):
This gasoline pre-treatment optional step to be desulfurization is to be used for removing the diolefine that gasoline exists to small part.This diene hydrogenation effect is a non-imposed but favourable step, and in fact this step can remove the whole diene that exist in the pending cut before hydrotreatment.These diolefine are polymeric natural gum precursors in hydrotreating reactor, and limit their life-span.
Carry out in the presence of a kind of catalyzer as this step 1, this catalyzer contains at least a group VIII metal, preferably is selected from VII family metal and a kind of carrier of platinum, palladium and nickel.For example use a kind of 1-20 of containing weight % to be deposited on inert support, like aluminum oxide, silicon-dioxide, silica-alumina, nickel aluminate, or contain the catalyzer of the nickel at least 50% alumina supporter.This catalyzer is usually pressure 0.4-5 MPa, temperature 50-250 ℃ and liquid hourly space speed 1-10 hour
-1Operate under the condition.Another group vib metal that can associate for example as molybdenum and tungsten, generates bimetallic catalyst.Associate as this group vib metal and group VIII metal, the group vib metal deposits on carrier up to 1-20 weight %.
The selection operation condition is a particularly important.More generally, comparing in the presence of the excessive a little amounts of hydrogen, under pressure, operate with the needed stoichiometric calculation value of hydrogenated diene hydrocarbon.Hydrogen and treating material are with the preferably catalyst fixed bed reactor of flow pattern injection up or down.This temperature more generally is 50-300 ℃, preferably 80-250 ℃, and more preferably 120-210 ℃.
This pressure should be selected to such an extent that be enough to make more than the 80 weight %, and preferably the above pending gasoline of 95 weight % remains in the reactor with liquid phase: its pressure more generally is the 0.4-5 MPa, preferably is higher than 1 MPa.Favourable pressure is between the 1-4 MPa, comprises its cut off value.
Under these conditions, space velocity is about 1-12 hour
-1, preferably 4-10 hour
-1
Lighting end can contain the diolefine up to percentum weight in the gasoline fraction of catalytic pyrolysis.After hydrogenization, diene content is reduced to below the 3000ppm, even below the 2500ppm, better below the 1500ppm.In some cases, can reach the diene content that is lower than 500ppm.Diene content behind the selective hydration in some cases even be reduced to below the 250ppm.
The diolefine selective hydrogenation is supervened the isomerization of outer olefinic double bonds, causes generating internal olefin.The result of this isomerization has generated by the saturated more resistant to elevated temperatures alkene of hydrogen, causes octane value to increase (or because of the low octane value that compensated of alkene loss) a little.This perhaps generally is higher than the reason of terminal olefine owing to the octane index of internal olefin.
According to one embodiment of the present invention, in the hydrogenation catalyticreactor, carry out the diene hydrogenation step, this reactor comprises at least one usually whole material and carries out the catalyzed reaction section that the necessary hydrogen amount of expected response is passed through.
2) light sulfocompound increases the weight of (step b)
This optional step is that promptly its boiling point is lower than the compound of thiophene boiling point with saturated light sulfide, changes into saturated sulfocompound, and its boiling point is higher than the compound of thiophene boiling point.These light sulfocompounds are mercaptan, the CS of 1-5 carbon atom typically
2With the sulfide that contains 2-4 carbon atom.This transformation preferably has the catalyzer of at least a group VIII (element classification periodictable the 8th, 9 and 10 families) element to carry out on aluminum oxide, silicon-dioxide or silica-alumina or nickel aluminate class carrier with a kind of.Selecting catalyst especially so that promote reaction between light mercaptans and the alkene, obtains mercaptan or sulfide that boiling point is higher than thiophene.
This optional step can randomly use same catalyzer and step a) to carry out simultaneously.For example, during the hydrogenated diene hydrocarbon, operation is particularly advantageous under the condition that the compound that is the mercaptan form as at least a portion is transformed.
In this case, these temperature generally are 100-300 ℃, preferably 150-250 ℃.H
2/ material ratio is adjusted to and whenever is upgraded to the 1-20 liter, preferably every liter of 3-15 liter.Space velocity generally is 1-10 hour
-1, preferably 2-6 hour
-1, pressure is the 0.5-5 MPa, preferably the 1-3 MPa.
3) gasoline be separated at least two kinds of cuts (step c):
This step is chosen wantonly.At step a) and b) after when carrying out this step, this step can produce the petroleum naphtha of desulfurization, this gasoline often contains the following mercaptan of 50ppm.In this step process, gasoline is fractionated at least two kinds of cuts:
-lighting end, the residual sulphur content of its cut is very limited, is preferably lower than about 50ppm, more preferably is lower than about 20ppm, most preferably is lower than about 10ppm, and need not be intended to reduce sulphur content other one or more handle and just can use this cut,
-last running has wherein concentrated most of sulphur, i.e. nascent whole sulphur in material, and the sulphur of not finding in petroleum naphtha.
Preferably use common distillation tower to carry out this separation.This separation column should be able to the gasoline lighting end that contains small portion sulphur with contain preferably that the last running of nascent most of sulphur separates in feed gasoline.
The petroleum naphtha that obtains by this separation generally contains whole at least five carbon atom alkene, preferably five carbon atom compounds and at least 20% six carbon atom alkene.Usually, at step a) and b) after this lighting end sulphur content that obtains very low, promptly do not need to handle this lighting end as last acting as a fuel to use.
The gasoline that a kind of alternative of the inventive method that use describes below is handled is directly to come the unitary pyrolysis gasoline of autothermic cracking, or the step a), the b that describe in front) or c) in the pretreated pyrolysis gasoline of at least one step.
Method of the present invention is included in two step d) and the f in two differential responses sections), and between two hydrodesulfurizationsection section, separate H
2The step e) of S.
(step d) is in the presence of hydrogen to first step of hydrogenating desulfurization, and at temperature 250-350 ℃, preferably 270-320 ℃ and pressure 1-3 MPa preferably under the 1.5-2.5 MPa, allow pending gasoline pass through Hydrobon catalyst.Liquid space velocity generally is 1-10 hour
-1, preferably 2-5 hour
-1, H
2/ HC is than being 50-500 liter/liter (l/l), preferably 100-400 liter/liter (l/l), more preferably 150-300 liter/liter (l/l).H
2/ HC ratio is at 1 normal atmosphere and the ratio of 0 ℃ of following hydrogen flowing quantity with flow of hydrocarbon.Under these conditions, this is reflected in the gas phase and carries out.The desulfurization degree that reaches in this step process strictly is higher than 90%, and the gasoline that promptly for example begins the 2000ppm sulphur that contains can change into the gasoline that contains the following sulphur of 200ppm.Operational condition should be regulated according to the characteristic for the treatment of material in this step process, reaches desulfurization degree and strictly is higher than 90%, preferably is higher than 92%, most preferably is higher than 94%.Effluent from this first hydrodesulfurisationstep step is the gasoline of partial desulfurization, and residual hydrogen and sulfocompound decompose the H that produces
2S.
After this step is most of H
2Separating step (the step e) of S and other effluent.This step is used for removing at least 80%, preferably at least 90% H that produces in the step d) process
2S.Can adopt the various different modes in most of mode known to those skilled in the art to remove H
2S.For example can enumerate a lot of metal oxide absorption H
2S, these metal oxides preferably are selected from zinc oxide, cupric oxide or molybdenum oxide.This adsorbent is preferably reproducible, and for example can regenerate with continuous or discontinuous manner by thermal treatment under oxidation or reductive atmosphere.Can in fixed bed or moving-bed, use this adsorbent.Another relatively classic methods be cooling step d) effluent, obtain a kind of liquid and a kind of H of being rich in
2And H
2The gas of S.Use the amine washing plant of those skilled in the art's well-known functions, can be with H
2S and H
2Separate.
Second step f) of desulfurization is the deep desulfurization of gasoline that is used for carrying out from step e), up to the sulphur content of looking for.This step is at temperature 200-300 ℃, and preferably 240-290 ℃, pressure 1-3 MPa preferably under the 1.5-2.5 MPa, allows gasoline from step e) mix with hydrogen and passes through Hydrobon catalyst.Liquid space velocity generally is 1-10 hour
-1, preferably 2-8 hour
-1, H
2/ HC is than being 50-500 liter/liter (l/l), preferably 100-400 liter/liter (l/l), more preferably 150-300 liter/liter (l/l).Under these conditions, in gas phase, carry out this reaction.Gasoline of handling in this step process and hydrogen mixture contain the H below the 100ppm
2S, the preferably following H of 50ppm
2S.The operational condition of this step should be that desulfurization degree can reach needed sulphur content, keeps desulfurization degree to be lower than the operational condition of first step desulfurization degree simultaneously.The treating material sulphur content is more much lower than the beginning material in this step process, and the desulfurization degree of looking for is also lower.Therefore, catalyst volume of Xu Yaoing and service temperature generally also are lower.For example, desulfurized step f) VVH (per hour volumetric velocity) can be higher 1.5 times than the VVH of step d), and/or desulfurized step f) temperature for example can be than low at least 10 ℃ of the temperature of step d), advantageously at least 20 ℃.Often, the volume of industrial equipments stagnant catalyst, at this moment, the desulfurization degree of step f) mainly is to regulate by temperature.But, by to step d) or f) in any known parameters of working of each step desulfurization degree, for example implementation step f) time use the catalyzer lower than step d) catalyst activity, can regulate described difference, do not exceed scope of the present invention.For example, step f) is used and to be contained than the low amount of metal of step d) catalyzer or than the catalyzer of small specific surface carrier, can obtain step d) and f) catalyzer between poor activity.Another terms of settlement is to use the catalyzer of part inactivation in step f).
Therefore, be adjusted in operational condition in the step f) process, often reach and strictly be higher than 80%, preferably be higher than 85%, most preferably be higher than 92%, even be higher than 95% desulfurization degree according to the treating material characteristic.
The difference of the desulfurization degree of first and second hydrodesulfurisationstep step generally is to be higher than 1% with absolute value representation, preferably is higher than 2%, most preferably is higher than 3%.
Astoundingly, the applicant in fact finds, step d) and f) separately this constraint condition of desulfurization degree that the sulfur in gasoline alcohol content of production is reduced to is minimum, make thus later any gasoline desulfur (alcohol) (adoucissement) step become non-imposed or less compulsory.
According to a kind of enforcement alternatives of the inventive method, also possible is to inject new hydrogen in second hydrodesulphurisatioreactors reactors, so that separate gasoline and the hydrogen that produces, and will generally contain the following H of 200ppm
2This hydrogen of S injects first hydrodesulfurisationstep step.
At step d) and f) catalyzer that uses in the process contains at least a group VIII element and/or at least a group vib element on suitable carrier.
The group VIII metal content of representing with oxide compound generally is 0.5-15 weight %, preferably 1-10 weight %.The group vib metal content generally is 1.5-60 weight %, preferably 3-50 weight %.
When having the group VIII element, it is cobalt preferably, and when having the group vib element, it usually is molybdenum or tungsten.This support of the catalyst is the porous solid normally, for example as aluminum oxide, silica-alumina or other porosu solid, for example as the magnesium oxide, silicon-dioxide or the titanium dioxide that use or mix with aluminum oxide or silica-alumina use separately.Minimum for the olefin hydrogenation effect that exists in the heavy petrol is reduced to, a kind of catalyzer of advantageously preferred use is wherein with per unit surface %MoO
3The molybdenum density that weight is represented is higher than 0.07, preferably is higher than 0.10.Catalyzer of the present invention preferably has specific surface less than 190 meters
2/ gram is more preferably less than 180 meters
2/ gram is most preferably less than 150 meters
2/ gram.
After adding one or more elements and shaping of catalyst (when this step uses the mixture that has contained fundamental element to carry out) randomly, first step activates this catalyzer.This activation may be that initial oxidation reduces then, perhaps directly reduction, perhaps only calcining.Calcining step is usually at the about 100-600 of temperature ℃, and preferably 200-450 ℃ is carried out under airflow.
The catalyzer that preferably is its sulfur-bearing form to the small part use.At whole activation step, i.e. can add sulphur before or after calcining or the reduction.Preferably, when adding sulphur or sulfocompound, do not carry out any catalyst oxidation step toward catalyzer.Sulphur or sulfocompound can be not on the spot, promptly implement to add outside the reactor of the inventive method, or on the spot, promptly add in the reactor that the inventive method is used.Under this latter event, reduce under the condition that this catalyzer is preferably described in front, allow the material that contains at least a sulfocompound by vulcanizing then, this sulfocompound is in case decomposition just causes sulphur to be fixed on this catalyzer.This material can be gas or liquid, for example contains H
2The hydrogen of S, or contain the liquid of at least a sulfocompound.
According to prior art embodiments 1 and 2 and embodiments of the invention 3 relatively, can prove meaning of the present invention and advantage.
Embodiment 1 (according to prior art)
Embodiment 1 relates to does not have the middle H that removes
2S, but the sulfur method of hydrodesulfurisationstep step is arranged.
With the aqueous solution of the cobalt of molybdenum that contains the Ammonium Heptamolybdate form and Xiao Suangu, " no excess solution " dipping transition alumina, its aluminum oxide is coccoid, 130 meters of specific surfaces
2/ gram, 0.9 milliliter/gram of pore volume can obtain Hydrobon catalyst A.This catalyzer carries out drying then, and calcines under 500 ℃ of air.The cobalt contents of this sample and molybdenum content are 3%CoO and 10%MoO
3
100 milliliters of catalyst A are put into tubular fixed-bed hydrodesulphurisatioreactors reactors.This catalyzer at first with by 2% just-be the material that the sulphur of dimethyl disulphide forms in the heptane to contact, 3.4 MPas, 350 ℃ of following sulfidizing 4 hours.
The material of handling is a kind of catalytic cracking gasoline, and it begins 50 ℃ of boiling points, 225 ℃ of full boiling points.Its sulphur content is 2000ppm by weight, and bromine index (IBr) is 69 grams/100 grams, and this is corresponding to about 36 weight % alkene.
This material uses catalyst A at pressure 2 MPas, H
2/ HC is than 300 liters/liter and VVH2 hour
-1Handle under the condition.Table 1 shows the influence of temperature to desulfurization degree and olefin saturation performance.
Table 1
| Temperature (℃) | The sulphur content of sweet gasoline (ppm) | Mercaptans content (ppm) | Desulfurization degree (%) | The IBr of sweet gasoline | Alkene saturation exponent (HDO) |
| ????310 | ????41 | ????32 | ????97.9 | ????20.3 | ????70.6 |
| ????320 | ????23 | ????20 | ????98.8 | ????14.7 | ????78.7 |
| ????330 | ????12 | ????11 | ????99.4 | ????10 | ????85.5 |
Using the very high sour gasoline of this class to reach 10ppm sulphur necessary operations condition is high temperature (＞310 ℃) and low VVH (2 hours
-1).Under these conditions, might reach desulfurization degree and be higher than 99%, but at this moment the alkene saturation exponent becomes very high (being higher than 85%), this is unfavorable for octane value.
Embodiment 2 (according to prior art)
Embodiment 2 relates to a kind of sulfur method according to prior art, and this method has two hydrodesulfurisationstep step and centre to remove to generate H
2S.
Under condition, use catalyst A than embodiment 1 milder.According to prior art, the desulfurization degree of second hydrodesulfurisationstep step is higher than the desulfurization degree of first step.The material of handling is identical with the material of embodiment 1.
In embodiment 1 reactor, this material mixes with hydrogen and is added to catalyst A.Service temperature is 285 ℃.Other concrete operations condition is listed in table 2.The effluent of reactor outlet contains 239ppm sulphur.These effluents cool off and stripping, so that with hydrogen in the hydrocarbon phase and H
2S separates.According to the operational condition of described second step of listing in the table 2, at this moment steam stripped effluent mixes to reinject with new hydrogen and is equipped with in the reactor of catalyst A.Mass flow should multiply by 1.5 with respect to the flow of first step.The experimental installation that uses comprises that online sulphur content analyses instrument, and this analyser can be measured the sulphur content in the effluent continuously.The temperature of reactor when regulating second step is so that obtain containing the gasoline of 10ppm sulphur.
Table 2
| First step | ||
| Temperature 1 | ????℃ | ????285 |
| VVH1 | Hour -1 | ????4 |
| Pressure 1 | Crust | ????20 |
| H 2/HC1 | Rise/liter | ????300 |
| The sulphur in exit | ????ppm | ????239 |
| Outlet IBr | ????49.9 | |
| HDS | ????％ | ????88.1 |
| Second step | ||
| Temperature 2 | ????℃ | ????292 |
| VVH2 | Hour -1 | ????6 |
| Pressure 2 | Crust | ????20 |
| H 2/HC2 | Rise/liter | ????300 |
| The sulphur in exit | ????ppm | ????10 |
| The mercaptan in exit | ????ppm | ????9 |
| Outlet IBr | ????36.9 | |
| HDS | ????％ | ????96.0 |
| Total HDS | ????％ | ????99.5 |
| Total HDO | ????％ | ????46.6 |
This embodiment shows and comprises that two hydrodesulfurisationstep step and centre remove H
2The method of S, more much higher than the selectivity of the method for implementing a step among the embodiment 1.In fact, gasoline that embodiment 2 produces and the gasoline of embodiment 1 have same sulphur content, but alkene saturation exponent (HDO) here is 46.7%, and embodiment 1 is 85.5%.The process of olefin saturation performance was reduced to minimum when therefore the method for implementing according to embodiment 2 can make and cause hydrogenating desulfurization.
Embodiment 3: the present invention
In this embodiment, with embodiment 2 on the contrary, the desulfurization degree of first step is higher than the desulfurization degree of second step.
The material of handling is identical with embodiment 1 and 2.
This material mixes with hydrogen in the previous reaction device of delivering to catalyst A.Service temperature is 300 ℃.Other operational condition is listed in table 3.The effluent of reactor outlet contains 117ppm sulphur respectively.Operating method is identical with embodiment's 2: these effluents cool off and stripping, so that with hydrogen in the hydrocarbon phase and H
2S separates, and according to the operational condition of listing in the table 3, hydrocarbon phase mixes to reinject with new hydrogen and is equipped with in the reactor of catalyst A.Mass flow should multiply by 1.5 with respect to the flow of first desulfurized step.As among the embodiment 2, attemperation is so that reclaim the gasoline that obtains containing 10ppm sulphur at reactor outlet at last.
Table 3
| First step | ||
| Temperature 1 | ????℃ | ????300 |
| VVH1 | Hour -1 | ????4 |
| Pressure 1 | MPa | ????2 |
| H 2/HC1 | Rise/liter | ????300 |
| The sulphur in exit | ????ppm | ????117 |
| Outlet IBr | ????43.4 | |
| HDS | ????％ | ????94.2 |
| Second step | ||
| Temperature 2 | ????℃ | ????264 |
| VVH2 | Hour -1 | ????6 |
| Pressure 2 | MPa | ????2 |
| H 2/HC2 | Rise/liter | ????300 |
| The sulphur in exit | ????ppm | ????10 |
| The mercaptan in exit | ????ppm | ????6 |
| Outlet IBr | ????36.8 | |
| HDS | ????％ | ????91.2 |
| Total HDS | ????％ | ????99.5 |
| Total HDO | ????％ | ????46.7 |
Method of the present invention, the desulfurization degree that promptly adopts the desulfurization degree of first step to be higher than second step can reach same sulphur content in sweet gasoline, and with the same alkene saturation exponent of prior art by embodiment 2 explanations.Yet the effluent that uses the inventive method to obtain contains the mercaptan than the gasoline that is obtained by embodiment 2 low 30%.Therefore, adopt the inventive method not only can limit the saturability of alkene greatly, but also reduce mercaptans content greatly, significantly reduced the corrodibility of producing gasoline like this.
Claims (12)
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| FR0204108A FR2837831B1 (en) | 2002-03-29 | 2002-03-29 | PROCESS FOR THE PRODUCTION OF HYDROCARBONS WITH LOW SULFUR CONTENT AND MERCAPTANS |
| FR02/04108 | 2002-03-29 |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN1448481A true CN1448481A (en) | 2003-10-15 |
Family
ID=27839409
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN03128651.8A Pending CN1448481A (en) | 2002-03-29 | 2003-03-29 | Method for production of low sulfur and thiol content hydrocarbon |
Country Status (5)
| Country | Link |
|---|---|
| US (1) | US20030217951A1 (en) |
| EP (1) | EP1354930A1 (en) |
| JP (1) | JP2003327970A (en) |
| CN (1) | CN1448481A (en) |
| FR (1) | FR2837831B1 (en) |
Cited By (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101205483B (en) * | 2005-12-22 | 2012-05-23 | 法国石油公司 | Selective hydrogenation process using supported catalysts |
| CN102533330A (en) * | 2010-12-31 | 2012-07-04 | 中国石油化工股份有限公司 | Method for producing low-sulfur gasoline |
| CN102604672A (en) * | 2011-01-20 | 2012-07-25 | 中国石油化工股份有限公司 | Method for producing low-sulfur gasoline |
Families Citing this family (19)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US7785461B2 (en) * | 2004-11-10 | 2010-08-31 | Petroleo Brasileiro S.A. - Petrobras | Process for selective hydrodesulfurization of naphtha |
| FR2895416B1 (en) * | 2005-12-22 | 2011-08-26 | Inst Francais Du Petrole | SELECTIVE HYDROGENATION PROCESS USING A SULFIDE CATALYST |
| BRPI0601787B1 (en) * | 2006-05-17 | 2016-06-07 | Petroleo Brasileiro Sa | selective naphtha hydrodesulfurization process |
| JP5123635B2 (en) * | 2007-10-12 | 2013-01-23 | Ｊｘ日鉱日石エネルギー株式会社 | Method for producing gasoline base material and gasoline |
| US8461293B2 (en) | 2010-08-03 | 2013-06-11 | Chevron Phillips Chemical Company Lp | Methods of mercaptanizing olefinic hydrocarbons and compositions produced therefrom |
| CN102634368B (en) * | 2011-02-10 | 2014-08-06 | 中国石油天然气股份有限公司 | A method for upgrading inferior gasoline |
| US8753504B2 (en) * | 2011-04-28 | 2014-06-17 | Battelle Memorial Institute | Systems and processes for removing elemental sulfur compounds from desulfurized fuels |
| US8821715B2 (en) * | 2011-05-24 | 2014-09-02 | Saudi Arabian Oil Company | Electrochemical promotion of catalysis in hydrodesulfurization processes |
| FR2988732B1 (en) * | 2012-03-29 | 2015-02-06 | IFP Energies Nouvelles | METHOD FOR SELECTIVELY HYDROGENATING A GASOLINE |
| FR3014896B1 (en) | 2013-12-18 | 2018-07-27 | IFP Energies Nouvelles | PROCESS FOR HYDRODESULFURIZATION OF HYDROCARBON CUT |
| FR3057578B1 (en) | 2016-10-19 | 2018-11-16 | IFP Energies Nouvelles | PROCESS FOR HYDRODESULFURING OLEFINIC ESSENCE |
| US12071592B2 (en) | 2017-02-12 | 2024-08-27 | Magēmā Technology LLC | Multi-stage process and device utilizing structured catalyst beds and reactive distillation for the production of a low sulfur heavy marine fuel oil |
| US12281266B2 (en) | 2017-02-12 | 2025-04-22 | Magẽmã Technology LLC | Heavy marine fuel oil composition |
| US11788017B2 (en) | 2017-02-12 | 2023-10-17 | Magëmã Technology LLC | Multi-stage process and device for reducing environmental contaminants in heavy marine fuel oil |
| US20190233741A1 (en) | 2017-02-12 | 2019-08-01 | Magēmā Technology, LLC | Multi-Stage Process and Device for Reducing Environmental Contaminates in Heavy Marine Fuel Oil |
| US12025435B2 (en) | 2017-02-12 | 2024-07-02 | Magēmã Technology LLC | Multi-stage device and process for production of a low sulfur heavy marine fuel oil |
| US10604709B2 (en) | 2017-02-12 | 2020-03-31 | Magēmā Technology LLC | Multi-stage device and process for production of a low sulfur heavy marine fuel oil from distressed heavy fuel oil materials |
| CN113546644B (en) * | 2021-06-27 | 2022-05-27 | 昆明理工大学 | Preparation method and application of catalyst for deep removal of organic sulfur from coke oven gas |
| FR3154412A1 (en) * | 2023-10-24 | 2025-04-25 | Axens | PROCESS FOR TREATING A PYROLYSIS GASOLINE |
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| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US3349027A (en) * | 1965-02-08 | 1967-10-24 | Gulf Research Development Co | Multi-stage hydrodesulfurization process |
| US4678408A (en) * | 1984-01-06 | 1987-07-07 | Pacesetter Infusion, Ltd. | Solenoid drive apparatus for an external infusion pump |
| US4685903A (en) * | 1984-01-06 | 1987-08-11 | Pacesetter Infusion, Ltd. | External infusion pump apparatus |
| US4562751A (en) * | 1984-01-06 | 1986-01-07 | Nason Clyde K | Solenoid drive apparatus for an external infusion pump |
| JP3387700B2 (en) * | 1995-07-26 | 2003-03-17 | 新日本石油株式会社 | Desulfurization method of catalytic cracking gasoline |
| US6231753B1 (en) * | 1996-02-02 | 2001-05-15 | Exxon Research And Engineering Company | Two stage deep naphtha desulfurization with reduced mercaptan formation |
| US6692635B2 (en) * | 1999-02-24 | 2004-02-17 | Institut Francais Du Petrole | Process for the production of gasolines with low sulfur contents |
| US6303020B1 (en) * | 2000-01-07 | 2001-10-16 | Catalytic Distillation Technologies | Process for the desulfurization of petroleum feeds |
| FR2807061B1 (en) * | 2000-03-29 | 2002-05-31 | Inst Francais Du Petrole | PROCESS FOR FUEL DESULFURIZATION COMPRISING DESULFURIZATION OF HEAVY AND INTERMEDIATE FRACTIONS FROM A FRACTIONATION IN AT LEAST THREE CUT |
| US6444118B1 (en) * | 2001-02-16 | 2002-09-03 | Catalytic Distillation Technologies | Process for sulfur reduction in naphtha streams |
-
2002
- 2002-03-29 FR FR0204108A patent/FR2837831B1/en not_active Expired - Lifetime
-
2003
- 2003-03-13 EP EP03290618A patent/EP1354930A1/en not_active Ceased
- 2003-03-28 JP JP2003090289A patent/JP2003327970A/en active Pending
- 2003-03-29 CN CN03128651.8A patent/CN1448481A/en active Pending
- 2003-03-31 US US10/402,152 patent/US20030217951A1/en not_active Abandoned
Cited By (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101205483B (en) * | 2005-12-22 | 2012-05-23 | 法国石油公司 | Selective hydrogenation process using supported catalysts |
| CN102533330A (en) * | 2010-12-31 | 2012-07-04 | 中国石油化工股份有限公司 | Method for producing low-sulfur gasoline |
| CN102533330B (en) * | 2010-12-31 | 2014-05-28 | 中国石油化工股份有限公司 | Method for producing low-sulfur gasoline |
| CN102604672A (en) * | 2011-01-20 | 2012-07-25 | 中国石油化工股份有限公司 | Method for producing low-sulfur gasoline |
| CN102604672B (en) * | 2011-01-20 | 2014-05-28 | 中国石油化工股份有限公司 | Method for producing low-sulfur gasoline |
Also Published As
| Publication number | Publication date |
|---|---|
| US20030217951A1 (en) | 2003-11-27 |
| EP1354930A1 (en) | 2003-10-22 |
| FR2837831A1 (en) | 2003-10-03 |
| JP2003327970A (en) | 2003-11-19 |
| FR2837831B1 (en) | 2005-02-11 |
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