CN1478866A - Method of gasoline desulfurization - Google Patents
Method of gasoline desulfurization Download PDFInfo
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- CN1478866A CN1478866A CNA021290393A CN02129039A CN1478866A CN 1478866 A CN1478866 A CN 1478866A CN A021290393 A CNA021290393 A CN A021290393A CN 02129039 A CN02129039 A CN 02129039A CN 1478866 A CN1478866 A CN 1478866A
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- Prior art keywords
- gasoline
- hydrogen
- hydrodesulfurization
- catalyst
- reaction
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Classifications
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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
- 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
- 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
- C10G45/12—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 crystalline alumino-silicates, e.g. molecular sieves
-
- 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
Abstract
A process for desulfurizing gasoline includes such steps as dividing raw gasoline into light gasoline fraction and heavy gasoline fraction, hydrodesulfurizing the heavy one, separating gas phase from the resultant by high-pressure separator, mixing residual liquid with fresh H2, hydrodesulfurizing again, separating H2-enriched gas by said separator for cyclic use, and stabilizing in stabilizing tower to obtain qualified product.
Description
Technical Field
The present invention relates to a process for refining hydrocarbon oils in the presence of hydrogen, and more particularly to a process for hydrogenating gasoline fractions.
Background
With the increasing awareness of the environment, the specifications of gasoline for vehicles, such as oxygen content, vapor pressure, benzene content, total aromatic content, boiling point, olefin content and sulfur content, will become more and more strict, especially sulfur content. At present, 90-99% of sulfur in domestic finished gasoline comes From Catalytic Cracking (FCC) gasoline, so that the reduction of the sulfur content of the catalytic cracking gasoline is the key point for reducing the sulfur content of the finished gasoline. The existing methods for producing low-sulfur gasoline abroad are many, and mainly comprise FCC raw material hydrogenation pretreatment (pre-hydrogenation), FCC gasoline post-treatment and combined application of the two methods.
The sulfur content in finished gasoline can be greatly reduced by the hydrogenation treatment of the FCC raw material, but the investment of the pretreatment of the FCC raw material is highest in all methods for reducing the sulfur content of the FCC gasoline, and the method is difficult to bear economically; when the sulfur content in the gasoline is required to be further reduced to below 30ppm, the pre-hydrogenation process obviously cannot meet the requirement, and a gasoline hydrogenation device is still required to be newly built; also, it should be noted that the pretreatment of the FCC feedstock does not reduce the olefin content of the FCC gasoline. Thus, if the olefin content of the FCC gasoline is too high, additional processing may be required.
FCC gasoline processing clearly has its unique advantages, interms of plant investment, production cost and hydrogen consumption, lower than the pretreatment of FCC feedstock with hydrogen. And the different desulfurization depths can meet the gasoline with different sulfur content specifications. However, the catalytic gasoline has high olefin content, and particularly the olefin content of domestic gasoline is far higher than that of foreign gasoline. The traditional hydrodesulfurization method can reduce the octane number of the gasoline due to the large-amount hydrogenation saturation of olefin. Therefore, the development of a low-sulfur gasoline production technology with low investment and small octane number loss is urgent.
US5,906,730 discloses a process for staged desulfurization of FCC gasoline. The desulfurization rate of the first stage is kept at 60-90%, and the process conditions are as follows: the temperature is 200-350 ℃, and the hydrogen partial pressure is 5-30 kg/cm2And the liquid hourly space velocity is 2-10 h-1The hydrogen-oil ratio is 500 to 3,000scf/bbl (i.e., 89 to 534 Nm)3/m3)，H2The concentration of S is controlled to be less than 1000 ppm. The second stage controls the desulfurization rate to be 60-90%, and the process conditions are as follows: the temperature is 200-300 ℃, and the hydrogen partial pressure is 5-15 kg/cm2And the liquid hourly space velocity is 2-10 h-1The hydrogen-oil ratio is 1,000 to 3,000scf/bbl (i.e., 178 to 534Nm3/m3)，H2The concentration of S is controlled to be less than 500 ppm. If the second stage of desulfurization still does not reach the pre-stageIn the end, the effluent of the secondary desulfurization outlet is continuously desulfurized under the same process conditions as the secondary desulfurization process conditions. The hydrogen sulfide concentration in the recycle hydrogen must be tightly controlled for each step.
EP1031622 discloses a process for hydrodesulfurizing full-range FCC gasoline. The first step is to hydrogenate and saturate unsaturated sulfur compounds in FCC gasoline to convert into mercaptan sulfur compounds, and the second step is to hydrogenate and desulfurize saturated sulfur compounds. Its advantages are full-range FCC gasoline processing, and no need of fractional distillation. The disadvantage is that the residual sulfur compounds in the final product are mostly mercaptan sulfur compounds, resulting in off-specification mercaptan sulfur in the product.
As the end point of domestic FCC gasoline is lower than that of foreign FCC gasoline, the olefin content of the FCC gasoline increases along with the reduction of the boiling point of the gasoline fraction, so that the olefin content of the domestic FCC gasoline is higher. The prior art is used for carrying out hydrodesulfurization on domestic FCC gasoline, and the olefin is saturated too much, so that the octane number loss is large.
After the heavy fraction of FCC gasoline is hydrodesulfurized, because the product still contains olefin and H2S generated by the reaction, mercaptan is easily generated by mutual reaction, and the mercaptan compounds are subjected to hydrodesulfurization reaction to generate corresponding hydrocarbon and H2S, wherein the reaction formula is as follows:
because the space velocity is high and the reaction temperature is low, part of mercaptan compounds leave a catalyst bed layer without hydrodesulfurization reaction, so that the product contains a small amount of mercaptan sulfur, and the mercaptan sulfur content in the final product is more than 10ppm and exceeds the gasoline index requirement. The conventional sweetening process is fixed bed oxidative sweetening, which reduces the mercaptan sulfur content by converting the mercaptan sulfur to disulfide, but without a reduction in total sulfur.
Disclosure of Invention
The invention aims to provide a method for desulfurizing gasoline on the basis of the prior art so as to reduce the content of mercaptan sulfur in the gasoline.
The method provided by the invention comprises the following steps:
cutting a gasoline raw material into a light gasoline fraction and a heavy gasoline fraction; the heavy gasoline fraction and hydrogen gas are contacted with a hydrodesulfurization catalyst together to carry out selective hydrodesulfurization reaction, the reaction effluent is separated into a gas phase by a high-pressure separator, the residual liquid phase is mixed with new hydrogen and then contacted with the hydrodesulfurization catalyst, and the effluent sequentially enters the high-pressure separator and a stabilizer to obtain a qualified product; the hydrogen-rich gas flow separated from the high-pressure separator is returned to the hydrotreating reactor for recycling after being pressurized by a circulating compressor.
The method provided by the invention can produce gasoline with mercaptan sulfur of less than 10ppm, and octane number is basically not lost in the hydrodesulfurization process.
Drawings
The attached drawing is a schematic diagram of the gasoline desulfurization method provided by the invention.
Detailed Description
The method provided by the invention is implemented as follows:
cutting a gasoline raw material into a light gasoline fraction and a heavy gasoline fraction; the heavy gasoline fraction and hydrogen gas are contacted with a hydrodesulfurization catalyst together to carry out selective hydrodesulfurization reaction, the reaction effluent is separated into a gas phase by a high-pressure separator, the residual liquid phase is mixed with new hydrogen and then contacted with the hydrodesulfurization catalyst, and the effluent sequentially enters the high-pressure separator and a stabilizer to obtain a qualified product; the hydrogen-rich gas flow separated from the high-pressure separator is returned to the hydrotreating reactor for recycling after being pressurized by a circulating compressor.
The gasoline raw material used in the invention is FCC gasoline, catalytic pyrolysis gasoline, straight run gasoline, coker gasoline, pyrolysis gasoline, thermal cracking gasoline or a mixture thereof, the distillation range is less than 220 ℃, and the sulfur content in the raw material is not more than 1500 ppm.
The reaction conditions for selective hydrodesulfurization are: the hydrogen partial pressure is 1.0-3.2 MPa, the reaction temperature is 200-320 ℃, the liquid hourly space velocity is 2.0-6.0 h<-1>, and the hydrogen-oil ratio is 200-600 Nm3/m 3. The reaction conditions for hydrogenation and mercaptan removal are as follows: the hydrogen partial pressure is 1.0-2.5 MPa, the reaction temperature is 200-300 ℃, the liquid hourly space velocity is 2.0-10.0 h<-1>, and the hydrogen-oil ratio is 200-600 Nm3/m 3. The reaction severity of hydrodesulphurisation is relatively less severe than that of selective hydrodesulphurisation.
Hydrodesulfurization catalysts and hydrodemercaptan removal catalysts are non-noble group VIB or VIII catalysts supported on amorphous alumina or silica-alumina carriers. The hydrodesulfurization catalyst and the hydrodethiolation catalyst may be the same or different.
The method provided by the invention is further explained in the following with reference to the attached drawings. But not to limit the invention accordingly.
The attached figure is a schematic diagram of the method for reducing mercaptan sulfur in hydrogenated gasoline provided by the invention.
The process flow for producing the low-sulfur gasoline is as follows:
FCC gasoline heavy distillate oil is fed into a raw material pump 2 through a pipeline 1 to be boosted, is mixed with circulating hydrogen from a pipeline 3, is fed into a heating furnace 5 through a pipeline 4 to be preheated, and then is fed into a reactor 7 through a pipeline 6 to be contacted with a hydrodesulfurization catalyst bed layer, so that impurities such as sulfur, nitrogen and the like in the raw material are removed. The effluent from the reactor 7 is fed via line 8 to a high pressure separator 9 where it is split into two streams, one of which is a hydrogen-rich stream, primarily hydrogen, comprising part of the hydrogen sulfide, ammonia and light hydrocarbons. The hydrogen-rich stream enters recycle compressor 22 via line 20. The other stream is mixed with fresh hydrogen from line 11 via line 10 and passed via line 12 to reactor 13 where the residual mercaptan sulfur is removed from the product. The outlet effluent from reactor 13 is passed via line 14 to high pressure separator 15 where it is split into two streams, one of which is a hydrogen-rich stream, primarily hydrogen. The hydrogen-rich gas stream is pressurized by recycle compressor 22 along with the hydrogen-rich gas stream from line 20 via line 21, mixed with fresh hydrogen from line 24 via line 23, and recycled to reactor 7 via line 3. The other stream enters the stabilization system 17 through a line 16, the stream which comes out from the bottom of the stabilization system 17 through a line 19 is the final product of the hydrogenation part, and the stream which comes out from the top of the stabilization system 17 through a line 18 is gas.
The catalyst in the hydrogenation process can be a VIB or VIII non-noble metal catalyst loaded on an amorphous alumina or silicon-aluminum carrier, the catalysts loaded in the reactors 7 and 13 can be the same or different, and the reaction severity in the reactor 13 is moderate compared with that in the reactor 7.
The method provided by the invention can be used for producing gasoline with mercaptan sulfur content lower than 10ppm, and the mercaptan sulfur content meets the II-type oil standard in the world fuel oil specification. The octane number is not lost in the hydrogenation sweetening process, and compared with an oxidation sweetening method, the hydrogenation sweetening method is cleaner and more environment-friendly.
The following examples further illustrate the process provided by the present invention, but are not intended to limit the invention thereto.
The hydrodesulfurization catalyst and the hydrodemercaptan removal catalyst used in the examples have trade designations of RSDS-1 and RSS-1A, respectively, and are produced by catalyst factories of the limited liability company of oil refining chemical industry, Changjin, China petrochemical group.
Comparative example
FCC gasoline A is used as a raw material, the raw material is cut firstly, and the obtained heavy gasoline fraction, hydrogen and a catalyst RSDS-1 are contacted at the hydrogen partial pressure of 1.6MPa, the reaction temperature of 290 ℃ and the liquid hourly space velocity of 4.0h-1Hydrogen to oil ratio of 400Nm3/m3Carrying out hydrodesulfurization under the condition; the effluent of the hydrodesulfurization reaction is subjected to a conventional oxidative sweeteningprocess. The properties of the fractions after hydrodesulfurization are shown in Table 1, and the process conditions and product properties for oxidative sweetening are shown in Table 2. As can be seen from Table 2, although the mercaptan sulfur content can be reduced to below 10ppm, the total sulfur is not reduced. In terms of environmental protection, the method for removing mercaptan by hydrogenation is cleaner and more environment-friendly.
Example 1
FCC gasoline A is used as a raw material, the raw material is cut firstly, and the obtained heavy gasoline fraction, hydrogen and a catalyst RSDS-1 are contacted at the hydrogen partial pressure of 1.6MPa, the reaction temperature of 290 ℃ and the liquid hourly space velocity of 4.0h-1Hydrogen to oil ratio of 400Nm3Nm3Carrying out hydrodesulfurization under the condition; different from the comparative example, the effluent of the hydrodesulfurization reaction is subjected to hydrodethiolation instead of oxidative sweetening, after the effluent of the hydrodesulfurization reaction is separated into a gas phase by a cold high-pressure separator, the residual liquid phase is mixed with new hydrogen and then is contacted with a catalyst RSS-1A, and the effluent sequentially enters a high-pressure separator and a stabilizing tower to obtain a qualified product; from highThe hydrogen-rich gas flow separated by the pressure separator is returned to the hydrotreating reactor for recycling after being pressurized by the circulating compressor. The properties of the fractions after hydrodesulfurization are shown in Table 1, and the process conditions and product properties for hydrodemercaptan removal are shown in Table 2. As can be seen from Table 2, the hydrodesulphurization can reduce the mercaptan content to below 10ppm and the total sulfur content can be further reduced, while the conventional oxidative sweetening method reduces the mercaptan sulfur content by converting the mercaptan sulfur into disulfide, and the total sulfur is not reduced. In terms of environmental protection, the hydrogenation sweetening is cleaner and more environmental-friendly. From the family composition data, the composition is almost unchanged after hydrogenation and mercaptan removal, and the octane number of the product is not lost.
Example 2
FCC gasoline B is used as a raw material, the raw material is cut firstly, and the obtained heavy gasoline fraction, hydrogen and a catalyst RSDS-1 are contacted at the hydrogen partial pressure of 1.6MPa, the reaction temperature of 300 ℃ and the liquid hourly space velocity of 4.0h-1Hydrogen to oil ratio of 400Nm3/m3Carrying out hydrodesulfurization under the condition; separating the effluent of the hydrodesulfurization reaction into a gas phase by a cold high-pressure separator, mixing the residual liquid phase with new hydrogen, and then contacting the mixture with a catalyst RSS-1A, wherein the effluent sequentially enters a high-pressure separator and a stabilizing tower to obtain a qualified product; the hydrogen-rich gas flow separated from the high-pressure separator is returned to the hydrotreating reactor for recycling after being pressurized by a circulating compressor. The properties of the hydrodesulfurized fractions are shown in Table 1The process conditions and product properties for hydrodethiolation are shown in Table 2. As can be seen from Table 2, the hydrodesulphurization can reduce the mercaptan content to below 10ppm, and the total sulphur content can be further reduced. From the family composition data, the composition is almost unchanged after hydrogenation and mercaptan removal, and the octane number of the product is not lost.
TABLE 1
| Removing heavy fraction A from gasoline Fraction after sulfur | Gasoline B heavy fraction desulfurization Fraction after the distillation | |
| Density (20 ℃ C.), g/cm3 | 0.7803 | 0.7658 |
| Sulfur content, ppm | 82 | 76 |
| Mercaptan sulfur content, ppm | 31 | 34 |
| Olefin content, wt.% | 16.8 | 21.2 |
| Distillation range, deg.C | ||
| Initial boiling point | 92 | 92 |
| 5％ | 105 | 106 |
| 50％ | 135 | 132 |
| End point of distillation | 190 | l73 |
| RON | 85.2 | 78.9 |
TABLE 2
| Comparative example | Example 1 | Example 2 | |
| Partial pressure of hydrogen, MPa | - | 1.6 | 1.6 |
| T，℃ | 40 | 240 | 240 |
| Liquid hourly space velocity, h-1 | 2.0 | 8.0 | 8.0 |
| Hydrogen to oil ratio, Nm3/m3 | - | 200 | 400 |
| After mercaptan removal Heavy gasoline fraction properties | |||
| Density (20 ℃ C.), g/cm3 | 0.7803 | 0.7803 | 0.7658 |
| Sulfur content, ppm | 82 | 60 | 50 |
| Mercaptan sulfur content, ppm | 3 | 9 | 9 |
| Group composition, weight% | |||
| Alkane hydrocarbons | 33.5 | 33.8 | 35.45 |
| Olefins | 16.8 | 16.5 | 21.1 |
| Cycloalkanes | 9.5 | 9.5 | 11.15 |
| Aromatic hydrocarbons | 40.2 | 40.2 | 32.3 |
| RON | 85.2 | 85.0 | 78.8 |
Claims (6)
1. A gasoline desulfurization method comprises cutting gasoline raw material into light gasoline fraction and heavy gasoline fraction; the heavy gasoline fraction and hydrogen gas are contacted with a hydrodesulfurization catalyst together to carry out selective hydrodesulfurization reaction, and the method is characterized in that after a gas phase of reaction effluent is separated by a high-pressure separator, the residual liquid phase is mixed with new hydrogen and then contacted with the hydrodesulfurization catalyst, and the effluent sequentially enters the high-pressure separator and a stabilizing tower to obtain a qualified product.
2. The process of claim 1 wherein said gasoline feedstock is catalytically cracked gasoline, straight run gasoline, coker gasoline, pyrolysis gasoline, thermally cracked gasoline, or mixtures thereof.
3. The process according to claim 1, characterized in that the reaction conditions of the selective hydrodesulfurization are: the hydrogen partial pressure is 1.0-3.2 MPa, the reaction temperature is 200-320 ℃, and the liquid hourly space velocity is 2.0-6.0 h-1Hydrogen to oil ratio of 200 to 600Nm3/m3。
4. The process according to claim 1, characterized in that the reaction conditions for hydrodesulphurization are: the hydrogen partial pressure is 1.0-2.5 MPa, the reaction temperature is 200-300 ℃, and the liquid hourly space velocity is 2.0-10.0 h-1Hydrogento oil ratio of 200 to 600Nm3/m3。
5. The process according to claim 1, characterized in that the hydrodesulfurization catalyst is a non-noble group VIB or VIII metal catalyst supported on an amorphous alumina or silica-alumina support.
6. The process according to claim 1, characterized in that the hydrodethiolation catalyst is a non-noble metal group VIB or VIII catalyst supported on an amorphous alumina or silico-alumina support.
Priority Applications (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CNB021290393A CN1234815C (en) | 2002-08-29 | 2002-08-29 | Method of gasoline desulfurization |
| KR1020030059798A KR101009469B1 (en) | 2002-08-29 | 2003-08-28 | A hydrogenation process for removing mercaptan from gasoline |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CNB021290393A CN1234815C (en) | 2002-08-29 | 2002-08-29 | Method of gasoline desulfurization |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN1478866A true CN1478866A (en) | 2004-03-03 |
| CN1234815C CN1234815C (en) | 2006-01-04 |
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Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CNB021290393A Expired - Lifetime CN1234815C (en) | 2002-08-29 | 2002-08-29 | Method of gasoline desulfurization |
Country Status (2)
| Country | Link |
|---|---|
| KR (1) | KR101009469B1 (en) |
| CN (1) | CN1234815C (en) |
Cited By (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101148616B (en) * | 2006-09-20 | 2010-09-22 | 中国石油化工股份有限公司 | Method for producing cleaning gasoline from pyrolysis gasoline |
| CN101037615B (en) * | 2006-03-15 | 2011-04-20 | 中国石油化工股份有限公司 | Catalytic cracking gasoline modification method |
| CN103087770A (en) * | 2011-10-28 | 2013-05-08 | 江苏佳誉信实业有限公司 | Clean gasoline production method through selective hydrogenation and desulfurization of catalytic gasoline |
| CN103525459A (en) * | 2013-10-11 | 2014-01-22 | 宁夏宝塔石化科技实业发展有限公司 | Separation process for gasoline selective hydrogenation product |
| CN103740405A (en) * | 2014-01-21 | 2014-04-23 | 湖北金鹤化工有限公司 | Alkali cleaning-extraction-hydrogenation combined process for producing low-sulfur-content gasoline |
| CN103740407A (en) * | 2014-01-21 | 2014-04-23 | 湖北金鹤化工有限公司 | Alkali cleaning-extraction-washing-hydrogenation combined process for producing low-sulfur-content gasoline |
Families Citing this family (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US9393538B2 (en) | 2014-10-10 | 2016-07-19 | Uop Llc | Process and apparatus for selectively hydrogenating naphtha |
| US9822317B2 (en) | 2014-10-10 | 2017-11-21 | Uop Llc | Process and apparatus for selectively hydrogenating naphtha |
-
2002
- 2002-08-29 CN CNB021290393A patent/CN1234815C/en not_active Expired - Lifetime
-
2003
- 2003-08-28 KR KR1020030059798A patent/KR101009469B1/en active IP Right Grant
Cited By (8)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN101037615B (en) * | 2006-03-15 | 2011-04-20 | 中国石油化工股份有限公司 | Catalytic cracking gasoline modification method |
| CN101148616B (en) * | 2006-09-20 | 2010-09-22 | 中国石油化工股份有限公司 | Method for producing cleaning gasoline from pyrolysis gasoline |
| CN103087770A (en) * | 2011-10-28 | 2013-05-08 | 江苏佳誉信实业有限公司 | Clean gasoline production method through selective hydrogenation and desulfurization of catalytic gasoline |
| CN103525459A (en) * | 2013-10-11 | 2014-01-22 | 宁夏宝塔石化科技实业发展有限公司 | Separation process for gasoline selective hydrogenation product |
| CN103740405A (en) * | 2014-01-21 | 2014-04-23 | 湖北金鹤化工有限公司 | Alkali cleaning-extraction-hydrogenation combined process for producing low-sulfur-content gasoline |
| CN103740407A (en) * | 2014-01-21 | 2014-04-23 | 湖北金鹤化工有限公司 | Alkali cleaning-extraction-washing-hydrogenation combined process for producing low-sulfur-content gasoline |
| CN103740405B (en) * | 2014-01-21 | 2015-07-01 | 长江大学 | Alkali cleaning-extraction-hydrogenation combined process for producing low-sulfur-content gasoline |
| CN103740407B (en) * | 2014-01-21 | 2015-07-01 | 武汉工程大学 | Alkali cleaning-extraction-washing-hydrogenation combined process for producing low-sulfur-content gasoline |
Also Published As
| Publication number | Publication date |
|---|---|
| KR20040019984A (en) | 2004-03-06 |
| KR101009469B1 (en) | 2011-01-19 |
| CN1234815C (en) | 2006-01-04 |
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| CX01 | Expiry of patent term |
Granted publication date: 20060104 |