US20040040893A1 - Stripping process and apparatus - Google Patents
Stripping process and apparatus Download PDFInfo
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- US20040040893A1 US20040040893A1 US10/228,516 US22851602A US2004040893A1 US 20040040893 A1 US20040040893 A1 US 20040040893A1 US 22851602 A US22851602 A US 22851602A US 2004040893 A1 US2004040893 A1 US 2004040893A1
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- 238000000034 method Methods 0.000 title claims abstract description 35
- 239000007788 liquid Substances 0.000 claims abstract description 48
- 229930195733 hydrocarbon Natural products 0.000 claims abstract description 47
- 150000002430 hydrocarbons Chemical class 0.000 claims abstract description 47
- 239000004215 Carbon black (E152) Substances 0.000 claims abstract description 45
- 238000010438 heat treatment Methods 0.000 claims abstract description 7
- 239000012530 fluid Substances 0.000 claims description 26
- 238000004891 communication Methods 0.000 claims description 25
- 239000003502 gasoline Substances 0.000 claims description 24
- 239000007789 gas Substances 0.000 claims description 22
- 238000000926 separation method Methods 0.000 claims description 19
- 238000009834 vaporization Methods 0.000 claims description 19
- 230000008016 vaporization Effects 0.000 claims description 19
- 125000004432 carbon atom Chemical group C* 0.000 claims description 14
- 239000001257 hydrogen Substances 0.000 claims description 14
- 229910052739 hydrogen Inorganic materials 0.000 claims description 14
- 239000003085 diluting agent Substances 0.000 claims description 11
- 150000001875 compounds Chemical class 0.000 claims description 10
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 8
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 claims description 8
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 8
- OTMSDBZUPAUEDD-UHFFFAOYSA-N Ethane Chemical compound CC OTMSDBZUPAUEDD-UHFFFAOYSA-N 0.000 claims description 4
- 229910002092 carbon dioxide Inorganic materials 0.000 claims description 4
- 239000001569 carbon dioxide Substances 0.000 claims description 4
- 239000002737 fuel gas Substances 0.000 claims description 4
- 229910052757 nitrogen Inorganic materials 0.000 claims description 4
- 125000004435 hydrogen atom Chemical class [H]* 0.000 claims 2
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 description 9
- 239000002283 diesel fuel Substances 0.000 description 5
- 239000006200 vaporizer Substances 0.000 description 5
- 238000007670 refining Methods 0.000 description 4
- 150000002431 hydrogen Chemical class 0.000 description 3
- 238000004088 simulation Methods 0.000 description 3
- 239000000571 coke Substances 0.000 description 2
- 238000005094 computer simulation Methods 0.000 description 2
- 238000004458 analytical method Methods 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 238000009835 boiling Methods 0.000 description 1
- 230000003197 catalytic effect Effects 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 238000004821 distillation Methods 0.000 description 1
- 239000000446 fuel Substances 0.000 description 1
- 239000000295 fuel oil Substances 0.000 description 1
- 239000003350 kerosene Substances 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 239000003921 oil Substances 0.000 description 1
- 238000000746 purification Methods 0.000 description 1
Images
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
- C10G7/00—Distillation of hydrocarbon oils
-
- 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
- C10G31/00—Refining of hydrocarbon oils, in the absence of hydrogen, by methods not otherwise provided for
- C10G31/06—Refining of hydrocarbon oils, in the absence of hydrogen, by methods not otherwise provided for by heating, cooling, or pressure treatment
-
- 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
- C10G47/00—Cracking of hydrocarbon oils, in the presence of hydrogen or hydrogen- generating compounds, to obtain lower boiling fractions
Definitions
- This invention relates to the field of hydrocarbon refining. More particularly, this invention relates to the purification of hydrocarbon streams.
- the hydrocarbon feedstocks are mixed with hydrogen and heated to a high temperature using heat exchangers and furnaces.
- Heavy components contained in some hydrocarbon feedstocks can cause coke formation in areas where a dry point occurs.
- the coke can plug the tubes in heat exchangers, furnaces, or other equipment. Therefore, it is necessary for heavy components to be removed from these hydrocarbon feedstocks to avoid problems with clogged equipment.
- a further object of the present invention is to provide an improved apparatus to be used in removing heavy components from a hydrocarbon feedstock which is economical in construction and reliable and efficient in operation.
- a process for removing heavy components from a hydrocarbon feedstock.
- the process comprises, consists of, or consists essentially of:
- a system or apparatus for removing heavy components from a hydrocarbon feedstock comprising, consisting of, or consisting essentially of:
- the third embodiment of the present invention is an apparatus comprising, consisting of, or consisting essentially of;
- the fourth embodiment of the present invention is an apparatus comprising, consisting of, or consisting essentially of:
- a first vessel defining a vaporization zone and a liquid-vapor separation zone
- the drawing is a partially cut away elevation of an apparatus representing one embodiment of the present invention.
- the process of this invention involves the removal of heavy components from a hydrocarbon feedstock.
- the hydrocarbon feedstock can be any hydrocarbon feedstock containing heavy components.
- This can include hydrocarbon streams in refineries such as naphtha, straight run naphtha, coker naphtha, catalytic gasoline, visbreaker naphtha, alkylate, isomerate, reformate, and the like and combinations thereof.
- This can also include gasoline such as, but not limited to, coker gasoline, thermally cracked gasoline, visbreaker gasoline, fluid catalytically cracked gasoline, heavy oil cracked gasoline, and the like and combinations thereof.
- Diesel fuels can also be used. Suitable diesel fuels include, but are not limited to, light cycle oil, kerosene, jet fuel, straight-run diesel, hydrotreated diesel, and the like and combinations thereof.
- the number of carbon atoms per molecule of heavy components in a particular hydrocarbon feedstock depends upon the boiling range of that feedstock. For example, heavy components will generally be heavier in diesel fuel than in gasoline.
- a heavy component can be any compound having at least 12 carbon atoms per molecule.
- the heavy components In gasoline, the heavy components contain in the range of from 12 to 35 carbon atoms per molecule. More often, the heavy components in gasoline contain in the range of from 12 to 25 carbon atoms per molecule.
- a hydrocarbon feedstock is charged to a vaporization zone where it is heated.
- the hydrocarbon feedstock can be mixed with a diluent gas prior to the heating.
- the ratio of diluent gas to the hydrocarbon feedstock is in the range of from about 0.1:1 to about 8:1.
- the ratio of diluent gas to the hydrocarbon feedstock is preferably in the range of from 0.1:1 to 2:1.
- the diluent gas is selected from the group consisting of hydrogen, nitrogen, carbon dioxide, methane, ethane, fuel gas, and combinations of any two or more thereof.
- the diluent gas is hydrogen.
- the hydrocarbon feedstock is preferably heated such that from about 75% to about 99% of the feedstock is vaporized. More preferably, 85% to 90% of the hydrocarbon feedstock is vaporized as a result of such heating.
- the temperature to which the hydrocarbon feedstock is heated can depend upon a variety of factors. Such factors can include the type of hydrocarbon feedstock, the pressure, and the amount of diluent gas used.
- the hydrocarbon feedstock can be heated to a temperature in the range of from about 100° F. to about 800° F.
- gasoline can be heated to a temperature in the range of from about 400° F. to about 600° F. More preferably, the gasoline is heated to a temperature in the range of from about 440° F. to about 550° F. Most preferably, the gasoline is heated to a temperature in the range of 460° F. to 510° F.
- the hydrocarbon feedstock is vaporized so as to form a first vapor stream and a first liquid stream. These streams pass into a liquid vapor separation zone, which is in fluid flow communication with the vaporization zone. Within the liquid-vapor separation zone, the first vapor stream and the first liquid stream are separated. The first vapor stream leaves the liquid-vapor separation zone overhead, while the first liquid stream flows from the liquid-vapor separation zone into the stripping zone which is in fluid flow communication with the liquid-vapor separation zone, in order to be stripped.
- the liquid-vapor separation zone and stripping zone are in the same vessel, which is in fluid flow communication with the vaporization zone.
- the vaporization zone, liquid-vapor separation zone, and stripping zone are all in separate vessels that are in fluid flow communication with each other.
- the vaporization zone and liquid-vapor separation zone are in the same vessel.
- the stripping zone is located in a separate vessel. Both vessels are in fluid flow communication with each other.
- the stripping zone comprises, consists of, or consists essentially of, in the range of from 2 to 4 theoretical trays.
- the first liquid stream is stripped in the stripping zone with a counter current flow of a gas so as to form a second vapor stream and a second liquid stream.
- the stripping gas is selected from the group consisting of hydrogen, nitrogen, carbon dioxide, methane, ethane, fuel gas, and combinations of any two or more thereof.
- the gas is hydrogen.
- the ratio of the stripping gas to the first liquid stream is in the range of from about 0.05:1 to about 6:1. More preferably, the ratio of the stripping gas to the first liquid stream is in the range of from 0.1:1 to 2.4:1.
- the type of molecules contained in the second vapor stream depends on the type of hydrocarbon feedstock. The molecules can be heavier in diesel fuel than in gasoline.
- the second vapor stream can contain molecules with up to about 25 carbon atoms per molecule.
- the second vapor stream can comprise compounds having in the range of from 2 to 15 carbon atoms per molecule.
- the type of molecules contained in the second liquid stream depends on the type of hydrocarbon feedstock.
- the second liquid stream can comprise compounds having at least 5 carbon atoms per molecule.
- the second liquid stream comprises compounds having at least 12 carbon atoms per molecule.
- the second liquid stream preferably comprises compounds having in the range of from 12 to 35 carbon atoms per molecule. More preferably for gasoline, the second liquid stream comprises compounds having in the range of from 12 to 25 carbon atoms per molecule.
- At least a portion of the second liquid stream can optionally be reboiled to form a boil-up vapor stream and a bottoms residue stream.
- the bottoms residue stream passes out of the reboiling vessel, while the boil-up vapor stream returns to the stripper column.
- a hydrocarbon feedstock enters vaporizer 100 , defining a vaporization zone, via conduit 102 , which is in fluid flow communication with vaporizer 100 .
- hydrogen can be mixed with the hydrocarbon feedstock via conduit 104 , which is in fluid flow communication with conduit 102 .
- About 85-90% of the hydrocarbon feedstock is vaporized in vaporizer 100 and passes to vessel 110 via conduit 108 , wherein conduit 108 connects vaporizer 100 and vessel 110 in fluid flow communication.
- Vessel 110 includes liquid-vapor separation zone 112 , where the vapor is separated from the liquid, thereby forming a first vapor stream and a first liquid stream.
- the first vapor stream passes out of vessel 110 via conduit 114 , which is in fluid flow communication with vessel 110 .
- the first liquid stream is stripped in stripping zone 116 also located in vessel 110 , which contains in the range of from 2 to 4 theoretical trays.
- Hydrogen enters stripping zone 116 via conduit 106 , which is in fluid flow communication with conduit 104 and vessel 110 .
- the stripping forms a second vapor stream and a second liquid stream.
- the second vapor stream also passes through liquid-vapor separation zone 112 and leaves vessel 110 via conduit 114 .
- the second liquid stream leaves vessel 110 via conduit 118 which is in fluid flow communication with vessel 110 .
- the second liquid stream can travel to reboiler 120 via conduit 118 , which is also in fluid flow communication with reboiler 120 .
- the second liquid stream is reboiled to form a bottoms residue stream, which leaves the reboiler via conduit 122 which is in fluid flow communication with reboiler 120 , and a boil up vapor stream which returns to vessel 110 via conduit 124 which is in fluid flow communication with reboiler 120 and vessel 110 .
- a computer model was used to simulate the stripping of naphtha.
- the naphtha composition used as an input to the computer model was obtained from analyses of products from ASTM D-86 distillations of naphtha.
- the mass flow of the naphtha stream was set at 487,256 pounds per hour.
- the heavy components for this simulation were mainly modeled as C 24 H 50 .
- the heavy components in the naphtha stream of this simulation had a mass flow of 2424 pounds per hour.
- about 87.7% of the naphtha feed was vaporized before stripping.
- the mass flow of the stream containing hydrogen was set at 6190 pounds per hour. Seventy percent of the hydrogen went to the vaporizer and thirty percent of the hydrogen went to the stripper.
- Mass flows of the heavy components are shown in the table for the feedstock before being contacted with hydrogen, before it is vaporized, for the first vapor stream and the first liquid stream, and for the second vapor stream and the second liquid stream.
- the second vapor stream has a significantly lower mass flow of heavy components than the first liquid stream has before it is stripped. Therefore, the inventive process is quite useful for removing heavy components.
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)
Abstract
A process and apparatus for stripping a hydrocarbon feedstock comprising: heating the feedstock forming a vapor stream and a liquid stream, separating the vapor stream from the liquid stream and then stripping the liquid stream with a counter-current flow of a gas.
Description
- This invention relates to the field of hydrocarbon refining. More particularly, this invention relates to the purification of hydrocarbon streams.
- It is well known in the art to strip hydrocarbon feedstocks with a gas. However, there are ever-present incentives for the development of new and/or more effective processes for stripping hydrocarbons since heavy components in hydrocarbon feedstocks can clog equipment.
- In many refining processes, the hydrocarbon feedstocks are mixed with hydrogen and heated to a high temperature using heat exchangers and furnaces. Heavy components contained in some hydrocarbon feedstocks can cause coke formation in areas where a dry point occurs. The coke can plug the tubes in heat exchangers, furnaces, or other equipment. Therefore, it is necessary for heavy components to be removed from these hydrocarbon feedstocks to avoid problems with clogged equipment.
- In addition, incomplete vaporization can cause problems in refining processes that do not tolerate liquids.
- Therefore, a novel stripping process and apparatus that effectively strips hydrocarbon feedstocks and also provides for a substantially vaporized feedstock for refining processes would be a significant contribution to the art and economy.
- It is an object of the present invention to provide an improved process for removing heavy components from a hydrocarbon feedstock which is economical and efficient.
- A further object of the present invention is to provide an improved apparatus to be used in removing heavy components from a hydrocarbon feedstock which is economical in construction and reliable and efficient in operation.
- In accordance with the first embodiment of the present invention, a process is provided for removing heavy components from a hydrocarbon feedstock. The process comprises, consists of, or consists essentially of:
- (a) heating a hydrocarbon feedstock wherein at least a portion of the hydrocarbon feedstock is vaporized so as to form a first vapor stream and a first liquid stream;
- (b) separating the first vapor stream and the first liquid stream;
- (c) stripping the first liquid stream with a counter current flow of a gas so as to form a second vapor stream and a second liquid stream; and
- (d) recovering the second vapor stream and the second liquid stream from the stripper column.
- In accordance with the second embodiment of the present invention a system or apparatus is provided for removing heavy components from a hydrocarbon feedstock comprising, consisting of, or consisting essentially of:
- (a) a vaporization zone; and
- (b) a vessel defining a liquid vapor separation zone and a stripping zone, the vessel being in fluid flow communication with the vaporization zone.
- The third embodiment of the present invention is an apparatus comprising, consisting of, or consisting essentially of;
- (a) a vaporization zone;
- (b) a liquid-vapor separation vessel in fluid flow communication with the vaporization zone; and
- (c) a stripping vessel in fluid flow communication with the liquid-vapor separation vessel.
- The fourth embodiment of the present invention is an apparatus comprising, consisting of, or consisting essentially of:
- (a) A first vessel defining a vaporization zone and a liquid-vapor separation zone;
- (b) a second vessel defining a stripping zone wherein the second vessel is in fluid flow communication with the first vessel.
- Other objects and advantages of the invention will be apparent from the detailed description of the invention and the appended claims.
- The drawing is a partially cut away elevation of an apparatus representing one embodiment of the present invention.
- The process of this invention involves the removal of heavy components from a hydrocarbon feedstock.
- The hydrocarbon feedstock can be any hydrocarbon feedstock containing heavy components. This can include hydrocarbon streams in refineries such as naphtha, straight run naphtha, coker naphtha, catalytic gasoline, visbreaker naphtha, alkylate, isomerate, reformate, and the like and combinations thereof. This can also include gasoline such as, but not limited to, coker gasoline, thermally cracked gasoline, visbreaker gasoline, fluid catalytically cracked gasoline, heavy oil cracked gasoline, and the like and combinations thereof. Diesel fuels can also be used. Suitable diesel fuels include, but are not limited to, light cycle oil, kerosene, jet fuel, straight-run diesel, hydrotreated diesel, and the like and combinations thereof.
- The number of carbon atoms per molecule of heavy components in a particular hydrocarbon feedstock depends upon the boiling range of that feedstock. For example, heavy components will generally be heavier in diesel fuel than in gasoline.
- Generally, a heavy component can be any compound having at least 12 carbon atoms per molecule. In gasoline, the heavy components contain in the range of from 12 to 35 carbon atoms per molecule. More often, the heavy components in gasoline contain in the range of from 12 to 25 carbon atoms per molecule.
- In the present invention a hydrocarbon feedstock is charged to a vaporization zone where it is heated. Optionally, the hydrocarbon feedstock can be mixed with a diluent gas prior to the heating. Generally, the ratio of diluent gas to the hydrocarbon feedstock is in the range of from about 0.1:1 to about 8:1. For gasoline in particular, the ratio of diluent gas to the hydrocarbon feedstock is preferably in the range of from 0.1:1 to 2:1. The diluent gas is selected from the group consisting of hydrogen, nitrogen, carbon dioxide, methane, ethane, fuel gas, and combinations of any two or more thereof. Preferably, the diluent gas is hydrogen. The hydrocarbon feedstock is preferably heated such that from about 75% to about 99% of the feedstock is vaporized. More preferably, 85% to 90% of the hydrocarbon feedstock is vaporized as a result of such heating. The temperature to which the hydrocarbon feedstock is heated can depend upon a variety of factors. Such factors can include the type of hydrocarbon feedstock, the pressure, and the amount of diluent gas used. Generally, the hydrocarbon feedstock can be heated to a temperature in the range of from about 100° F. to about 800° F. Generally, gasoline can be heated to a temperature in the range of from about 400° F. to about 600° F. More preferably, the gasoline is heated to a temperature in the range of from about 440° F. to about 550° F. Most preferably, the gasoline is heated to a temperature in the range of 460° F. to 510° F.
- The hydrocarbon feedstock is vaporized so as to form a first vapor stream and a first liquid stream. These streams pass into a liquid vapor separation zone, which is in fluid flow communication with the vaporization zone. Within the liquid-vapor separation zone, the first vapor stream and the first liquid stream are separated. The first vapor stream leaves the liquid-vapor separation zone overhead, while the first liquid stream flows from the liquid-vapor separation zone into the stripping zone which is in fluid flow communication with the liquid-vapor separation zone, in order to be stripped. In the second embodiment of the invention, the liquid-vapor separation zone and stripping zone are in the same vessel, which is in fluid flow communication with the vaporization zone. In the third embodiment of the invention, the vaporization zone, liquid-vapor separation zone, and stripping zone are all in separate vessels that are in fluid flow communication with each other. In the fourth embodiment, the vaporization zone and liquid-vapor separation zone are in the same vessel. The stripping zone is located in a separate vessel. Both vessels are in fluid flow communication with each other. The stripping zone comprises, consists of, or consists essentially of, in the range of from 2 to 4 theoretical trays.
- The first liquid stream is stripped in the stripping zone with a counter current flow of a gas so as to form a second vapor stream and a second liquid stream. The stripping gas is selected from the group consisting of hydrogen, nitrogen, carbon dioxide, methane, ethane, fuel gas, and combinations of any two or more thereof. Preferably, the gas is hydrogen. Preferably, the ratio of the stripping gas to the first liquid stream is in the range of from about 0.05:1 to about 6:1. More preferably, the ratio of the stripping gas to the first liquid stream is in the range of from 0.1:1 to 2.4:1. The type of molecules contained in the second vapor stream depends on the type of hydrocarbon feedstock. The molecules can be heavier in diesel fuel than in gasoline. In diesel fuel for example, the second vapor stream can contain molecules with up to about 25 carbon atoms per molecule. For gasoline, the second vapor stream can comprise compounds having in the range of from 2 to 15 carbon atoms per molecule. The type of molecules contained in the second liquid stream depends on the type of hydrocarbon feedstock. Generally, the second liquid stream can comprise compounds having at least 5 carbon atoms per molecule. Preferably, the second liquid stream comprises compounds having at least 12 carbon atoms per molecule. For gasoline, the second liquid stream preferably comprises compounds having in the range of from 12 to 35 carbon atoms per molecule. More preferably for gasoline, the second liquid stream comprises compounds having in the range of from 12 to 25 carbon atoms per molecule.
- In another embodiment at least a portion of the second liquid stream can optionally be reboiled to form a boil-up vapor stream and a bottoms residue stream. The bottoms residue stream passes out of the reboiling vessel, while the boil-up vapor stream returns to the stripper column.
- Referring to the drawing, therein is illustrated the second embodiment of the present invention referred to as
apparatus 10, a hydrocarbon feedstock entersvaporizer 100, defining a vaporization zone, viaconduit 102, which is in fluid flow communication withvaporizer 100. Optionally, hydrogen can be mixed with the hydrocarbon feedstock viaconduit 104, which is in fluid flow communication withconduit 102. About 85-90% of the hydrocarbon feedstock is vaporized invaporizer 100 and passes tovessel 110 viaconduit 108, whereinconduit 108 connectsvaporizer 100 andvessel 110 in fluid flow communication.Vessel 110 includes liquid-vapor separation zone 112, where the vapor is separated from the liquid, thereby forming a first vapor stream and a first liquid stream. The first vapor stream passes out ofvessel 110 viaconduit 114, which is in fluid flow communication withvessel 110. The first liquid stream is stripped in strippingzone 116 also located invessel 110, which contains in the range of from 2 to 4 theoretical trays. Hydrogen enters strippingzone 116 viaconduit 106, which is in fluid flow communication withconduit 104 andvessel 110. The stripping forms a second vapor stream and a second liquid stream. The second vapor stream also passes through liquid-vapor separation zone 112 and leavesvessel 110 viaconduit 114. The second liquid stream leavesvessel 110 viaconduit 118 which is in fluid flow communication withvessel 110. Optionally, the second liquid stream can travel toreboiler 120 viaconduit 118, which is also in fluid flow communication withreboiler 120. The second liquid stream is reboiled to form a bottoms residue stream, which leaves the reboiler viaconduit 122 which is in fluid flow communication withreboiler 120, and a boil up vapor stream which returns tovessel 110 viaconduit 124 which is in fluid flow communication withreboiler 120 andvessel 110. - The following example is provided to further illustrate this invention and is not to be considered as unduly limiting the scope of this invention.
- This example illustrates the stripping of hydrocarbons using the inventive process.
- A computer model was used to simulate the stripping of naphtha. The naphtha composition used as an input to the computer model was obtained from analyses of products from ASTM D-86 distillations of naphtha. The mass flow of the naphtha stream was set at 487,256 pounds per hour. The heavy components for this simulation were mainly modeled as C24H50. The heavy components in the naphtha stream of this simulation had a mass flow of 2424 pounds per hour. In this simulation, about 87.7% of the naphtha feed was vaporized before stripping. The mass flow of the stream containing hydrogen was set at 6190 pounds per hour. Seventy percent of the hydrogen went to the vaporizer and thirty percent of the hydrogen went to the stripper.
- The mass flows of the heavy components are shown in the table for the feedstock before being contacted with hydrogen, before it is vaporized, for the first vapor stream and the first liquid stream, and for the second vapor stream and the second liquid stream.
Mass Flow (lb/hr) of Heavy Stream Components Before being contacted with 2424 hydrogen Before vaporization 2424 1st vapor stream 76.4 1st liquid stream 2348 2nd vapor stream 38.7 2nd liquid stream 2309 - The second vapor stream has a significantly lower mass flow of heavy components than the first liquid stream has before it is stripped. Therefore, the inventive process is quite useful for removing heavy components.
Claims (31)
1. A process comprising the steps of:
(a) heating a hydrocarbon feedstock wherein at least a portion of said hydrocarbon feedstock is vaporized so as to form a first vapor stream and a first liquid stream;
(b) separating said first vapor stream and said first liquid stream;
(c) stripping said first liquid stream with a counter-current flow of a gas so as to form a second vapor stream and a second liquid stream; and
(d) recovering said second vapor stream and said second liquid stream.
2. A process in accordance with claim 1 wherein said stripping occurs in a stripper column comprising in the range of from 2 to 4 theoretical trays.
3. A process in accordance with claim 1 wherein said second liquid stream comprises compounds having at least 5 carbon atoms per molecule.
4. A process in accordance with claim 1 wherein said second liquid stream comprises compounds having at least 12 carbon atoms per molecule.
5. A process in accordance with claim 1 wherein said hydrocarbon feedstock is heated in step (a) to a temperature in the range of from about 100° F. to about 800° F.
6. A process in accordance with claim 1 wherein said hydrocarbon feedstock is mixed with a diluent gas prior to said heating in step (a).
7. A process in accordance with claim 6 wherein the ratio of said diluent gas to said hydrocarbon feedstock is in the range of from about 0.1:1 to about 8:1.
8. A process in accordance with claim 6 wherein said diluent gas is selected from the group consisting of hydrogen, nitrogen, carbon dioxide, methane, ethane, fuel gas, and combinations of any two or more thereof.
9. A process in accordance with claim 1 further comprising the step of:
(e) reboiling at least a portion of said second liquid stream to form a boil-up vapor stream and a bottoms residue stream for return of said boil-up vapor stream to said stripper column.
10. A process in accordance with claim 1 wherein said hydrocarbon feedstock is heated in step (a) such that from about 75% to about 99% of said hydrocarbon feedstock is vaporized.
11. A process in accordance with claim 1 wherein said hydrocarbon feedstock is heated in step (a) such that from 85% to 90% of said hydrocarbon feedstock is vaporized.
12. A process in accordance with claim 1 wherein said gas in step (c) is selected from the group consisting of hydrogen, nitrogen, carbon dioxide, methane, ethane, fuel gas, and combinations of any two or more thereof.
13. A process in accordance with claim 12 wherein the ratio of said gas in step (c) to said first liquid stream is in the range of from about 0.05:1 to about 6:1.
14. A process in accordance with claim 12 wherein the ratio of said gas in step (c) to said first liquid stream is in the range of from 0.1:1 to 2.4:1.
15. A process in accordance with claim 1 wherein said hydrocarbon feedstock comprises gasoline.
16. A process in accordance with claim 15 wherein said second liquid stream comprises compounds having in the range of from 12 to 35 carbon atoms per molecule.
17. A process in accordance with claim 15 wherein said second liquid stream comprises compounds having in the range of from 12 to 25 carbon atoms per molecule.
18. A process in accordance with claim 15 wherein said gasoline is heated in step (a) to a temperature in the range of from about 400° F to about 600° F.
19. A process in accordance with claim 15 wherein said gasoline is heated in step (a) to a temperature in the range of from about 440° F. to about 550° F.
20. A process in accordance with claim 15 wherein said gasoline is heated in step (a) to a temperature in the range of from 460° F. to 510° F.
21. A process in accordance with claim 15 wherein said gasoline is mixed with a diluent gas prior to said heating in step (a).
22. A process in accordance with claim 21 wherein the ratio of said diluent gas to said gasoline is in the range of from 0.1:1 to 2:1.
23. An apparatus comprising:
(a) a vessel defining a vaporization zone;
(b) a vessel defining a liquid-vapor separation zone and a stripping zone, said vessel being in fluid flow communication with said vaporization zone.
24. An apparatus in accordance with claim 23 further comprising a reboiler in fluid flow communication with said vessel.
25. An apparatus in accordance with claim 23 wherein said vessel comprises from 2 to 4 theoretical trays.
26. An apparatus comprising:
(a) a vaporization vessel defining a vaporization zone;
(b) a liquid-vapor separation vessel defining a liquid-vapor separation zone in fluid flow communication with said vaporization zone; and
(c) a stripping vessel defining a stripping zone in fluid flow communication with said liquid-vapor separation vessel.
27. An apparatus in accordance with claim 26 further comprising a reboiler in fluid flow communication with said stripping vessel.
28. An apparatus in accordance with claim 26 wherein said stripping vessel comprises from 2 to 4 theoretical trays.
29. An apparatus comprising:
(a) A first vessel defining a vaporization zone and a liquid-vapor separation zone;
(b) a second vessel defining a stripping zone wherein said second vessel is in fluid flow communication with said first vessel.
30. An apparatus in accordance with claim 29 further comprising a reboiler in fluid flow communication with said second vessel.
31. An apparatus in accordance with claim 29 wherein said second vessel comprises from 2 to 4 theoretical trays.
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US10/228,516 US20040040893A1 (en) | 2002-08-27 | 2002-08-27 | Stripping process and apparatus |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US10/228,516 US20040040893A1 (en) | 2002-08-27 | 2002-08-27 | Stripping process and apparatus |
Publications (1)
Publication Number | Publication Date |
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US20040040893A1 true US20040040893A1 (en) | 2004-03-04 |
Family
ID=31976045
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
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US10/228,516 Abandoned US20040040893A1 (en) | 2002-08-27 | 2002-08-27 | Stripping process and apparatus |
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US (1) | US20040040893A1 (en) |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20210324275A1 (en) * | 2018-10-23 | 2021-10-21 | Haldor Topsøe A/S | Method for fractionation of hydrocarbons |
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---|---|---|---|---|
US2357710A (en) * | 1942-08-01 | 1944-09-05 | Lummus Co | Distillation of hydrocarbons |
US3210271A (en) * | 1962-02-19 | 1965-10-05 | Shell Oil Co | Fractionation with side stripping |
US4424117A (en) * | 1981-06-01 | 1984-01-03 | Masaya Kuno | Hydrostripping process of crude oil |
US4521295A (en) * | 1982-12-27 | 1985-06-04 | Hri, Inc. | Sustained high hydroconversion of petroleum residua feedstocks |
US4666562A (en) * | 1982-09-27 | 1987-05-19 | Kerr-Mcgee Refining Corporation | Solvent recovery from solvent process material mixtures |
US6454932B1 (en) * | 2000-08-15 | 2002-09-24 | Abb Lummus Global Inc. | Multiple stage ebullating bed hydrocracking with interstage stripping and separating |
US6550274B1 (en) * | 2001-12-05 | 2003-04-22 | Air Products And Chemicals, Inc. | Batch distillation |
-
2002
- 2002-08-27 US US10/228,516 patent/US20040040893A1/en not_active Abandoned
Patent Citations (7)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2357710A (en) * | 1942-08-01 | 1944-09-05 | Lummus Co | Distillation of hydrocarbons |
US3210271A (en) * | 1962-02-19 | 1965-10-05 | Shell Oil Co | Fractionation with side stripping |
US4424117A (en) * | 1981-06-01 | 1984-01-03 | Masaya Kuno | Hydrostripping process of crude oil |
US4666562A (en) * | 1982-09-27 | 1987-05-19 | Kerr-Mcgee Refining Corporation | Solvent recovery from solvent process material mixtures |
US4521295A (en) * | 1982-12-27 | 1985-06-04 | Hri, Inc. | Sustained high hydroconversion of petroleum residua feedstocks |
US6454932B1 (en) * | 2000-08-15 | 2002-09-24 | Abb Lummus Global Inc. | Multiple stage ebullating bed hydrocracking with interstage stripping and separating |
US6550274B1 (en) * | 2001-12-05 | 2003-04-22 | Air Products And Chemicals, Inc. | Batch distillation |
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US20210324275A1 (en) * | 2018-10-23 | 2021-10-21 | Haldor Topsøe A/S | Method for fractionation of hydrocarbons |
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Owner name: PHILLIPS PETROLEUM COMPANY, OKLAHOMA Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:HUNT, HAROLD R.;REEL/FRAME:013236/0362 Effective date: 20020827 |
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