HYDROCARBON UPGRADING PROCESS

Abstract: A hydrocarbon feedstock containing C5 olefins, C5 diolefins, CPD, DCPD, and aromatics is processed by the steps of heating a hydrocarbon feedstock (102) containing CPD, DCPD, C5 diolefins, benzene, toluene, and xylene in a heating zone (100), to dimerize CPD to DCPD, thereby forming a first effluent (104); separating the first effluent into a C6+ stream (110) and a C5 diolefin stream (108); separating the C6+ stream into a C6-C9 stream (114) and a C10+ stream; separating the C10+ stream into a fuel oil stream (134) and a DCPD stream (132); and hydrotreating the C6-C9 stream to thereby form a BTX stream.

Description: HYDROCARBON UPGRADING PROCESS The present invention relates to the field of hydrocarbon upgrading processes. More specifically, the present invention relates to the upgrading of a pyrolysis gasoline, obtained from a hydrocarbon thermal cracking process, to products such as C 5 diolefins, C 5 olefins, dicyclopentadiene, and aromatics such as benzene, toluene and xylene (BTX). BACKGROUND OF THE INVENTION By "consisting essentially of herein it is intended to mean that the substance or combination of substances recited after this phrase does not include any further components which would materially affect the properties of the substances or combination of substances recited after this phrase. It is well known in the art that processes for thermal cracking of hydrocarbons such as ethane, propane, naphtha, and the like, produce a by-product referred to as pyrolysis gasoline or aromatic concentrate, which can be debutanized to form debutanized aromatic concentrate (DAC). This pyrolysis gasoline or DAC typically contains C 5 and heavier hydrocarbons, such as C 5 diolefins, C 5 olefins, aromatics, cyclopentadiene (CPD), and dicyclopentadiene (DCPD). It is desirable to convert the CPD to DCPD which is a valuable industrial chemical which can be used in the production of elastomers and unsaturated polyester resins. Typical pyrolysis gasoline upgrading processes separate the pyrolysis gasoline into a C 5 stream containing CPD and a C 6 + stream. The C 5 stream is then dimerized to form DCPD which is purified downstream. One problem with this process is that when the pyrolysis gasoline is obtained from storage, wherein a portion of the CPD is converted to DCPD, the separation of the pyrolysis gasoline into a C 5 stream and a C 6 + stream, and dimerization of CPD in the C 5 stream to DCPD, will result in splitting the DCPD between the C 5 stream and the C 6 + stream, necessitating the added expense of recovering DCPD from both the C 5 stream and the C 6 + stream. Therefore, development of a process capable of efficiently upgrading a pyrolysis gasoline, obtained either directly from a hydrocarbon thermal cracking unit or from storage, would be a significant contribution to the art. SUMMARY OF THE INVENTION It is desirable to provide a novel process for upgrading a hydrocarbon feedstock comprising C 5 olefins, C 5 diolefins, CPD, DCPD and aromatics to produce a DCPD product and/or a C 5 diolefin product and/or a C 5 olefin product and/or an aromatic product. It is also desirable to provide a novel process of increased efficiency for recovering DCPD from pyrolysis gasoline. Again it is desirable to provide a novel process of increased efficiency for producing and recovering DCPD from pyrolysis gasoline containing a significant quantity of DCPD. Once again it is desirable to provide a novel process of increased efficiency for recovering DCPD from pyrolysis gasoline wherein the DCPD has a Pt/Co color number below about 30. In accordance with a first embodiment of the present invention, a process for upgrading hydrocarbons is provided including the steps of: a) heating a hydrocarbon feedstock comprising CPD, DCPD, C 5 diolefins, benzene, toluene, and xylene in a heating zone, to dimerize CPD to DCPD, thereby forming a first effluent; b) separating the first effluent into a C 6 + stream and a C 5 diolefin stream comprising C 5 diolefins; c) separating the C 6 + stream into a C 6 - C 9 stream and a C 10 + stream; d) separating the C ]0 + stream into a fuel oil stream and a DCPD stream comprising DCPD; and e) hydrotreating the C 6 - C 9 stream to thereby form a BTX stream comprising benzene, toluene and xylene. In accordance with a second embodiment of the present invention, a process for upgrading hydrocarbons is provided including the steps of: a) heating a hydrocarbon feedstock comprising CPD, DCPD, C 5 diolefins, benzene, toluene, and xylene in a heating zone, to dimerize CPD to DCPD, thereby forming a first effluent; b) separating the first effluent into a C 5 - C 9 stream and a C 10 + stream; c) separating the C 10 + stream into a fuel oil stream and a DCPD stream comprising DCPD; d) contacting the C 5 - C 9 stream with a selective hydrogenation catalyst, in a first reaction zone and in the presence of hydrogen, to hydrogenate at least a portion of the diolefins, alkynes, and styrene contained in the C 5 - C 9 stream, thereby forming a second effluent; e) separating the second effluent into a C 6 - C 9 stream and a C 5 olefin stream comprising C 5 olefins; f) contacting the C 6 - C 9 stream with a hydrodesulfurization catalyst, in a second reaction zone and in the presence of hydrogen, to desulfurize at least a portion of the sulfur-containing compounds contained in the C 6 - C 9 stream thereby forming a BTX stream comprising benzene, toluene and xylene. In accordance with a third embodiment of the present invention, a process for recovering DCPD from a hydrocarbon feedstock is provided including the steps of: a) providing a first separation column, a first overhead condenser, and a first reboiler, the first separation column defining a first separation zone having an upper portion, a lower portion and an intermediate portion, the intermediate portion of the first separation zone comprising at least about 50 theoretical trays; b) providing a second separation column, a second overhead condenser, and a second reboiler, the second separation column defining a second separation zone having an upper portion, a lower portion and an intermediate portion, the intermediate portion of the second separation zone comprising at least about 9 theoretical trays; c) introducing a hydrocarbon feedstock comprising DCPD to the intermediate portion of the first separation zone; d) allowing a first vaporous overhead stream comprising C 9 - hydrocarbons, and having a pressure in the range of from about 0.5 psia to about 3.0 psia and a temperature in the range of from about 160°F to about 200°F, to pass from the upper portion of the first separation column to the first overhead condenser; e) condensing at least a portion of the first vaporous overhead stream in the first overhead condenser thereby forming a first condensate having a temperature in the range of from about 50°F to about 90°F; f) refluxing at least a portion of the first condensate from the first overhead condenser to the upper portion of the first separation zone; g) allowing a first liquid bottoms stream comprising C 10 + hydrocarbons to pass from the lower portion of the first separation column to the first reboiler; h) reboiling at least a portion of the first liquid bottoms stream in the first reboiler at a temperature in the range of from about 210°F to about 250°F thereby forming a first reboiled stream and a remaining portion of the first liquid bottoms stream; i) introducing the first reboiled stream to the lower portion of the first separation zone; j) introducing the remaining portion of the first liquid bottoms stream to the intermediate portion of the second separation zone; k) allowing a second vaporous overhead stream comprising DCPD, and having a pressure in the range of from about 0.1 psia to about 2.0 psia and a temperature in the range of from about 160°F to about 200°F, to pass from the upper portion of the second separation zone to the second overhead condenser; 1) condensing at least a portion of the second vaporous overhead stream in the second overhead condenser thereby forming a second condensate having a temperature in the range of from about 70°F to about 100°F; m) refluxing at least a portion of the second condensate to the upper portion of the second separation zone and thereby forming a remaining portion of the second condensate; n) allowing a second liquid bottoms stream comprising fuel oil to pass from the lower portion of the second separation zone to the second reboiler; o) reboiling at least a portion of the second liquid bottoms stream in the second reboiler at a temperature in the range of from about 190°F to about 240°F thereby forming a second reboiled stream; p) introducing the second reboiled stream to the lower portion of the second separation zone; and q) recovering the remaining portion of the second condensate from the second overhead condenser thereby forming a DCPD stream. Other objects and advantages will become apparent from the detailed description and the appended claims. BRIEF DESCRIPTION OF THE DRAWINGS Figure 1 is a schematic flow diagram presenting an embodiment of the present invention. Figure 2 is a schematic flow diagram presenting another embodiment of the present invention. Figure 3 is a schematic flow diagram presenting yet another embodiment of the present invention. DETAILED DESCRIPTION OF THE INVENTION The process of this invention involves the upgrading of a hydrocarbon feedstock comprising CPD, DCPD, C 5 diolefins, benzene, toluene, and xylene. The hydrocarbon feedstock generally comprises hydrocarbons having greater than 4 carbon atoms per molecule. The hydrocarbon feedstock can be a pyrolysis gasoline from a thermal hydrocarbon (such as ethane, propane and naphtha) cracking process. The hydrocarbon feedstock can also be a pyrolysis gasoline which has been debutanized, and is generally referred to as DAC. The hydrocarbon feedstock typically contains in the range of from about 1.0 wt. % to about 20 wt. % CPD, more typically from about 1.0 wt. % to about 15 wt. % CPD, and most typically from 1.5 wt. % to 10 wt. % CPD, based on the total weight of the hydrocarbon feedstock; and, typically contains in the range of from about 0.5 wt. % to about 50 wt. % DCPD, more typically from about 1.0 wt. % to about 40 wt. % DCPD, and most typically from 1.5 wt. % to 30 wt. % DCPD, based on the total weight of the hydrocarbon feedstock. In accordance with the first embodiment of the invention, the hydrocarbon feedstock is heated in a heating zone in such a manner as to provide the dimerization of at least a portion of the CPD contained in the hydrocarbon feedstock to DCPD, thereby forming a first effluent. More particularly, the heating in the heating zone is conducted at a temperature in the range of from about 100°F to about 450°F, preferably from about 200°F to about 400°F, and most preferably from 200°F to 300°F. The wt. % of CPD in the first effluent is preferably less than about 2 wt. %, more preferably less than about 1.5 wt. %, and most preferably less than 1 wt. %, based on the total weight of the first effluent. The first effluent can then be separated, by any means, such as distillation, into a C 6 + stream comprising hydrocarbons having greater than 5 carbon atoms per molecule, and a C 5 diolefin stream comprising C 5 diolefins, such as, but not limited to, isoprene and cis and trans 1,3 pentadiene (piperylene). The C 6 + stream can be separated, by any suitable means, such as distillation, into a C 6 - C 9 stream comprising hydrocarbons having in the range of from and including 6 to and including 9 carbon atoms per molecule and into a C ]0 + stream comprising hydrocarbons having greater than 9 carbon atoms per molecule. The C 6 - C 9 stream typically contains sulfur in the range of from about 10 to about 200 ppmw, more typically in the range of from about 10 to about 100 ppmw, and most typically from 10 to 50 ppmw, based on the total weight of the C 6 - C 9 stream. The C 6 - C 9 stream also typically has a bromine number in the range of from about 10 to about 100, more typically from about 10 to about 50, and most typically from 10 to 30 grams of bromine/100 grams of sample. The bromine number, as referred to herein, is determined using ASTM test method D 1492-96 and is an indicator of the amount of olefins contained in a hydrocarbon stream. A low bromime number indicates low levels of olefins. The C 10 + stream can be separated, by any suitable means, such as distillation, into a fuel oil stream comprising hydrocarbons having greater than 10 carbon atoms per molecule, and into a DCPD stream comprising DCPD. The C 6 - C 9 stream can be hydrotreated, by any suitable means for hydrotreating hydrocarbons, to thereby form a BTX stream comprising benzene, toluene and xylene. More particularly, the hydrotreating can be accomplished by contacting the C 6 - C 9 stream with a hydrogenation catalyst, in a first reaction zone and in the presence of hydrogen, to hydrogenate at least a portion of the olefins, diolefins, alkynes, and styrene contained in the C 6 - C 9 stream, thereby forming a second effluent having a lower bromine number than the C 6 - C 9 stream. The first reaction zone can be operated as a batch process step or, preferably, as a continuous process step. In the latter operation, a solid catalyst bed or a moving catalyst bed or a fluidized catalyst bed can be employed. Any of these operational modes have advantages and disadvantages, and those skilled in the art can select the one most suitable for a particular feed and catalyst. The hydrogenation catalyst can be any composition effective for hydrogenating unsaturated hydrocarbons. More particularly, the hydrogenation catalyst can comprise, consist of, or consist essentially of a Group VIII metal selected from the group consisting of iron, cobalt, nickel, ruthenium, rhodium, palladium, osmium, iridium, platinum and combinations of any two or more thereof. Preferably, the hydrogenation catalyst comprises palladium. The hydrogenation in the first reaction zone is preferably carried out under reaction conditions effective for hydrogenating unsaturated hydro-carbons. The reaction temperature is more particularly in the range of from about 100°F to about 600°F, preferably from about 150°F to about 400°F, and most preferably from 150°F to 370°F. The contacting pressure can range from about 15 psia to about 1000 psia, preferably from about 50 psia to about 500 psia, and most preferably from 150 psia to 500 psia. The WHSV can be in the range of from about 0.1 hr. "1 to about 40 hr. "1 , preferably from about 0.25 hr. "1 to about 20 hr. "1 , and most preferably from 1.0 hr. "1 to 10 hr. "1 . The hydrogen to hydrocarbon ratio can be in the range of from about 10 to about 5000 standard cubic feet of hydrogen per barrel of hydrocarbon, preferably from about 20 to about 2500, and most preferably from 100 to 1000. The second effluent can be contacted with a hydrodesulfurization catalyst, in a second reaction zone and in the presence of hydrogen, to desulfurize at least a portion of the sulfur-containing compounds contained in the second effluent, and to saturate substantially most of the olefinic and diolefinic compounds contained in the second effluent, thereby forming the BTX stream. The BTX stream preferably contains less than about 2 ppmw, more preferably less than about 1.5 ppmw, and most preferably less than 1.0 ppmw sulfur, based on the total weight of the BTX stream. The BTX stream also preferably has a bromine number in the range of from about 0 to about 2, preferably from about 0 to about 1 , and most preferably from 0 to 0.5. The second reaction zone can be operated as a batch process step or, preferably, as a continuous process step. In the latter operation, a solid catalyst bed or a moving catalyst bed or a fluidized catalyst bed can be employed. Any of these operational modes have advantages and disadvantages, and those skilled in the art can select the one most suitable for a particular feed and catalyst. The hydrodesulfurization catalyst can be any composition effective for desulfurizing sulfur containing hydrocarbon feedstocks. More particularly, the hydrodesulfurization catalyst can comprise, consist of, or consist essentially of a Group VIII metal selected from the group consisting of iron, cobalt, nickel, ruthenium, rhodium, palladium, osmium, iridium, platinum, and combinations of any two or more thereof, and a Group VIB metal selected from the group consisting of chromium, molybdenum, tungsten, and combinations of any two or more thereof. Preferably, the hydrodesulfurization catalyst comprises nickel and molybdenum. The hydrodesulfurization in the second reaction zone is preferably carried out under reaction conditions effective for reducing the sulfur content of sulfur-containing hydrocarbons and effective for saturating olefinic hydrocarbons. The reaction temperature is more particularly in the range of from about 300°F to about 800°F; preferably from about 400°F to about 700°F; and most preferably from 500°F to 650°F. The contacting pressure can range from about 15 psia to about 1000 psia, preferably from about 50 psia to about 500 psia, and most preferably from 150 psia to 500 psia. The WHSV can be in the range of from about 0.1 hr. '1 to about 40 hr. "1 , preferably from about 0.25 hr. "1 to about 20 hr. "1 , and most preferably from 1.0 hr. "1 to 10 hr. "1 . The hydrogen to hydrocarbon ratio can be in the range of from about 10 to about 5000 standard cubic feet of hydrogen per barrel of hydrocarbon, preferably from about 20 to about 2500, and most preferably from 100 to 1000. In accordance with the second embodiment of the invention, the hydrocarbon feedstock, as described above, is heated in a heating zone in such a manner as to provide the dimerization of at least a portion of the CPD contained in the hydrocarbon feedstock to DCPD, thereby forming a first effluent. More particularly, the heating in the heating zone is conducted at a temperature in the range of from about 100°F to about 450°F, preferably from about 200°F to about 400°F, and most preferably from about 200°F to 300°F. The wt. % of CPD in the first effluent is preferably less than about 2 wt. %, more preferably less than about 1.5 wt. %, and most preferably less than 1 wt. %, based on the total weight of the first effluent. The first effluent can then be separated, by any means, such as distillation, into a C 10 + stream comprising hydrocarbons having greater than 9 carbon atoms per molecule, and a C 5 - C, stream comprising hydrocarbons having in the range of from and including 5 to and including 9 carbon atoms per molecule. The C 5 - C 9 stream typically contains sulfur in the range of from about 10 ppmw to about 200 ppmw, more typically from about 10 ppmw to 100 ppmw, and most typically from 10 to 50 ppmw, based on the total weight of the C 5 - C 9 stream. The C 5 - C 9 stream also typically has a bromine number in the range of from about 10 to about 200, more typically from about 10 to about 100, and most typically from 10 to 60. The C 10 + stream can be separated, by any suitable means, such as distillation, into a fuel oil stream comprising hydrocarbons having greater than 10 carbon atoms per molecule, and into a DCPD stream. The C 5 - C 9 stream can be contacted with a selective hydrogenation catalyst, in a first reaction zone and in the presence of hydrogen, to hydrogenate at least a portion of the diolefins, alkynes, and styrene contained in the C 5 - C 9 stream, thereby forming a second effluent having a lower bromine number than the C 5 - C 9 stream. The first reaction zone can be operated as a batch process step or, preferably, as a continuous process step. In the latter operation, a solid catalyst bed or a moving catalyst bed or a fluidized catalyst bed can be employed. Any of these operational modes have advantages and disadvantages, and those skilled in the art can select the one most suitable for a particular feed and catalyst. The selective hydrogenation catalyst can be any composition effective for selectively hydrogenating C 5 diolefins to C 5 olefins. More particularly, the selective hydrogenation catalyst can comprise, consist of, or consist essentially of a first component comprising a palladium-containing material selected from the group consisting of palladium metal, palladium oxides, and combinations of any two or more thereof; and a second component selected from the group consisting of silver, or an alkali-metal halide. When the second component is silver, the catalyst can be further promoted with an alkali-metal fluoride. Suitable selective hydrogenation catalysts, and methods of making such, are disclosed in U.S. Patent No. 5,866,735, and in U.S. Patent No. 5,510,550, which are each incorporated herein by reference. Preferably, the selective hydrogenation catalyst comprises palladium, silver and potassium fluoride or palladium and potassium iodide. Alkali-metal, as used herein, includes lithium, sodium, potassium, rubidium, cesium and francium. The hydrogenation in the first reaction zone is preferably carried out under reaction conditions effective for hydrogenating unsaturated hydrocarbons. The reaction temperature is more particularly in the range of from about 100°F to about 600°F, preferably from about 150°F to about 400°F, and most preferably from 150°F to 370°F. The contacting pressure can range from about 15 psia to about 1000 psia, preferably from about 50 psia to about 500 psia, and most preferably from 150 psia to 500 psia. The WHSV can be in the range of from about 0.1 hr. "1 to about 40 hr. "1 , preferably from about 0.25 hr. "1 to about 20 hr. "1 , and most preferably from 1.0 hr. "1 to 10 hr. "1 . The hydrogen to hydrocarbon ratio can be in the range of from about 10 to about 5000 standard cubic feet of hydrogen per barrel of hydrocarbon, preferably from about 20 to about 2500, and most preferably from 100 to 1000. The second effluent can be separated, by any suitable means, such as distillation, into a C 6 - C 9 stream comprising hydrocarbons having in the range of from and including 6 to and including 9 carbon atoms per molecule and into a C 5 olefin stream comprising C 5 olefins. The C 6 - C 9 stream can be contacted with a hydrodesulfurization catalyst, as described in the first embodiment, in a second reaction zone and in the presence of hydrogen, to desulfurize at least a portion of the sulfur-containing compounds contained in the C 6 - C 9 stream, and to saturate substantially most of the olefinic and diolefinic compounds contained in the C 6 - C 9 stream, thereby forming a BTX stream comprising benzene, toluene and xylene. The BTX stream preferably contains less than about 2 ppmw, more preferably less than about 1.5 ppmw, and most preferably less than 1.0 ppmw sulfur, based on the total weight of the BTX stream. The BTX stream also preferably has a bromine number in the range of from about 0 to about 2, more preferably from about 0 to about 1, and most preferably from 0 to 0.5. The second reaction zone can be operated as a batch process step or, preferably, as a continuous process step. In the latter operation, a solid catalyst bed or a moving catalyst bed or a fluidized catalyst bed can be employed. Any of these operational modes have advantages and disadvantages, and those skilled in the art can select the one most suitable for a particular feed and catalyst. The hydrodesulfurization in the second reaction zone is preferably carried out under reaction conditions effective for reducing the sulfur content of sulfur-containing hydrocarbons and effective for saturating olefinic hydrocarbons. The reaction temperature is more particularly in the range of from about 300°F to about 800°F; preferably from about 400°F to about 700°F; and most preferably from 500°F to 650°F. The contacting pressure can range from about 15 psia to about 1000 psia, preferably from about 50 psia to about 500 psia, and most preferably from 150 psia to 500 psia. The WHSV can be in the range of from about 0.1 hr. "1 to about 40 hr. "1 , preferably from about 0.25 hr. "1 to about 20 hr. "1 , and most preferably from 1 hr. '1 to 10 hr " '. The hydrogen to hydrocarbon ratio can be in the range of from about 10 to about 5000 standard cubic feet of hydrogen per barrel of hydrocarbon, preferably from about 20 to about 2500, and most preferably from 100 to 1000. In accordance with the third embodiment of the invention, DCPD can be recovered from a hydrocarbon feedstock comprising DCPD. The hydrocarbon feedstock can be the C 6 + stream from the first embodiment, or the first effluent from the second embodiment, or any hydrocarbon stream comprising DCPD including, but not limited to, pyrolysis gasoline as described above. A first separation column, a first overhead condenser, and a first reboiler are provided. The first separation column defines a first separation zone having an upper portion, a lower portion, and an intermediate portion. The intermediate portion of the first separation zone comprises at least about 50 theoretical trays, preferably at least about 55 theoretical trays, and most preferably at least 60 theoretical trays. A second separation column, a second overhead condenser, and a second reboiler are provided. The second separation column defines a second separation zone having an upper portion, a lower portion, and an intermediate portion. The intermediate portion of the second separation zone comprises at least about 9 theoretical trays, preferably at least about 10 theoretical trays, and most preferably at least 11 theoretical trays. The hydrocarbon feedstock can be introduced to the intermediate portion of the first separation zone. The theoretical tray location where the hydrocarbon feedstock is introduced to the intermediate portion of the first separation zone can be in the range of from about 10 to about 30, preferably from about 10 to about 20, and most preferably from 15 to 20. A first vaporous overhead stream comprising C 9 - hydrocarbons (hydrocarbons having less than 10 carbon atoms per molecule), and having a pressure in the range of from about 0.5 psia to about 3.0 psia, preferably from about 0.5 psia to about 2.0 psia, and most preferably from 1.0 psia to 1.5 psia and a temperature in the range of from about 160°F to about 200°F, preferably from about 170°F to about 200°F, and most preferably from 180°F to 200°F, is allowed to pass from the upper portion of the first separation column to the first overhead condenser wherein at least a portion of the first vaporous overhead stream is condensed, thereby forming a first condensate. The first condensate has a temperature in the range of from about 50°F to about 90°F, more preferably from about 50°F to about 80°F, and most preferably from 50°F to 70°F. At least a portion of the first condensate can be refluxed to the upper portion of the first separation zone at a reflux ratio in the range of from about 0.1 to about 1.0, preferably from about 0.2 to about 0.7, and most preferably from 0.3 to 0.5. Reflux ratio, as used herein, refers to the volume of condensate returned to the upper portion of a separation column divided by the remaining volume of condensate which is not returned to the separation column. The remaining portion of the first condensate (which is not refluxed) can be passed downstream for further processing. The remaining portion of the first condensate represents the C 6 - C 9 stream in the first embodiment or the C 5 - C 9 stream in the second embodiment. A first liquid bottoms stream comprising C 10 + hydrocarbons is allowed to pass from the lower portion of the first separation column to the first reboiler wherein at least a portion of the first liquid bottoms stream is reboiled, thereby forming a first reboiled stream, at a temperature in the range of from about 210°F to about 250°F, preferably from about 210 °F to about 240°F, and most preferably from 220°F to 230°F. The first reboiled stream can be introduced to the lower portion of the first separation zone. The remaining portion of the first liquid bottoms stream, which represents the C 10 + stream in both the first and second embodiments, can be introduced to the intermediate portion of the second separation zone. The theoretical tray location where the remaining portion of the first liquid bottoms stream is introduced to the intermediate portion of the second separation zone can be in the range of from about 2 to about 8, preferably from about 3 to about 7, and most preferably from 4 to 6. A second vaporous overhead stream comprising DCPD, and having a pressure in the range of from about 0.1 psia to about 2.0 psia, preferably from about 0.2 psia to about 1.0 psia, and most preferably from 0.3 psia to 0.6 psia and a temperature in the range of from about 160°F to about 200°F, preferably from about 180°F to about 200°F, and most preferably from 190°F to 200°F, is allowed to pass from the upper portion of the second separation column to the second overhead condenser wherein at least a portion of the second vaporous overhead stream is condensed, thereby forming a second condensate. The second condensate has a temperature in the range of from about 70°F to about 100°F, preferably from about 80°F to about 100°F, and more preferably from 90°F to 100°F. At least a portion of the second condensate can be refluxed to the upper portion of the second separation zone at a reflux ratio in the range of from about 0.1 to about 1.0, preferably from about 0.2 to about 0.7, and most preferably from 0.3 to 0.5. The remaining portion of the second condensate (which is not refluxed) can be passed downstream for further processing. The remaining portion of the second condensate represents the dicyclopentadiene stream in both the first and second embodiments. A second liquid bottoms stream comprising fuel oil is allowed to pass from the lower portion of the second separation column to the second reboiler wherein at least a portion of the second liquid bottoms stream is reboiled, thereby forming a second reboiled stream, at a temperature in the range of from about 190°F to about 240°F, preferably from about 190°F to about 220°F, and most preferably from 190°F to 210°F. The second reboiled stream can be introduced to the lower portion of the second separation zone. The remaining portion of the second liquid bottoms stream represents the fuel oil stream in both the first and second embodiments. The DCPD stream produced in the first, second, or third embodiment can comprise at least about 70 wt. % DCPD, preferably at least about 75 wt. % DCPD, and most preferably at least 80 wt. % DCPD, based on the total weight of the DCPD stream, and has a Pt-Co color which is less than about 30, preferably less than about 28, and most preferably less than 25. Pt-Co color, as used herein, is defined as the color of the liquid measured according to ASTM method D-1209. In order to avoid the production of color bodies from the reaction of DCPD, and other hydrocarbon compounds, with oxygen or rust, the first separation column, first overhead condenser, first reboiler, second separation column, second overhead condenser, and second reboiler must be operated in the substantial absence of rust and oxygen. More particularly, it is preferred to operate the first separation column, first overhead condenser, first reboiler, second separation column, second overhead condenser, and second reboiler, and any ancillary equipment, in an air tight mode. Also, it is preferred to clean, either chemically or otherwise, the first separation column, first overhead condenser, first reboiler, second separation column, second overhead condenser, second reboiler, and any ancillary equipment, prior to their use in the inventive process to remove substantially all of the rust contained therein. The process of the present invention will now be described with reference to the Figures. Referring to Figure 1, and the first embodiment of the present invention, a hydrocarbon feedstock enters a vessel 100, which defines a heating zone, via conduit 102, thereby forming a first effluent. The first effluent is removed from vessel 100 via conduit 104. The first effluent is then introduced to a first separation column 106, which defines a first separation zone, via conduit 104, and is separated into a C 6 + stream and a C 5 diolefin stream. The C 5 diolefin stream is removed from first separation column 106 via conduit 108 and the C 6 + stream is removed from first separation column 106 via conduit 110. The C 6 + stream is then introduced to a second separation column 112, which defines a second separation zone, via conduit 110, and is separated into a C 6 - C 9 stream and a C 10 + stream. The C 6 - C 9 stream is removed from second separation column 112 via conduit 114 and the C 10 + stream is removed from the second separation column 112 via conduit 116. The C 6 - C 9 stream and a hydrogen stream are then charged to a first reactor 118, which defines a first reaction zone, via conduits 114 and 120, respectively, and contact a hydrogenation catalyst contained within the first reaction zone, thereby forming a second effluent. The second effluent is removed from the first reactor 118 via conduit 122. The second effluent and a hydrogen stream are then charged to a second reactor 124, which defines a second reaction zone, via conduits 122 and 126, respectively, and contact a hydrodesulfurization catalyst contained within the second reaction zone, thereby forming a BTX stream. The BTX stream is removed from second reactor 124 via conduit 128. The C 10 + stream is introduced to a third separation column 130, which defines a third separation zone, via conduit 116, and is separated into a DCPD stream and a fuel oil stream. The DCPD stream is removed from third separation column 130 via conduit 132 and the fuel oil stream is removed from third separation column 130 via conduit 134. Referring now to Fig. 2, and the second embodiment of the present invention, a hydrocarbon feedstock enters a vessel 200, which defines a heating zone, via conduit 202, thereby forming a first effluent. The first effluent is removed from vessel 200 via conduit 204. The first effluent is then introduced to a first separation column 206, which defines a first separation zone, via conduit 204, and is separated into a C 5 - C 9 stream and a C 10 + stream. The C 5 - C 9 is removed from first separation column 206 via conduit 208 and the C 10 + stream is removed from the first separation column 206 via conduit 210. The C 5 - C 9 stream and a hydrogen stream are then charged to a first reactor 212, which defines a first reaction zone, via conduits 208 and 214, respectively, and contact a hydrogenation catalyst contained within the first reaction zone, thereby forming a second effluent. The second effluent is removed from first reactor 212 via conduit 216. The second effluent is then introduced to a second separation column 218, which defines a second separation zone, via conduit 216, and is separated into a C 6 - C 9 stream and a C 5 olefin stream. The C 5 olefin stream is removed from second separation column 218 via conduit 220 and the C 6 - C 9 stream is removed from second separation column 218 via conduit 222. The C 6 - C 9 stream and a hydrogen stream are then charged to a second reactor 224, which defines a second reaction zone, via conduits 222 and 226, respectively, and contact a hydrodesulfurization catalyst contained within the second reaction zone, thereby forming a BTX stream which is removed from second reactor 224 via conduit 228. The C 10 + stream is introduced to a third separation column 230, which defines a third separation zone, via conduit 210, and is separated into a DCPD stream and a fuel oil stream. The DCPD stream is removed from third separation column 230 via conduit 232 and the fuel oil stream is removed from third separation column 230 via conduit 234. Referring now to Fig. 3, and the third embodiment of the present invention, the hydrocarbon feedstock, which can be the C 6 + stream from the first embodiment or the first effluent from the second embodiment or any hydrocarbon feedstock comprising DCPD, enters a first separation column 300, which defines a first separation zone having an upper portion 304, a lower portion 306, and an intermediate portion 308, via conduit 302. The hydrocarbon feedstock enters first separation column 300 at the intermediate portion 308. A first vaporous overhead stream is passed from upper portion 304 to a first overhead condenser 310 via conduit 312, wherein at least a portion of the first vaporous overhead stream is condensed, thereby forming a first condensate. At least a portion of the first condensate is refluxed to upper portion 304 via conduit 314. The remaining portion of the first condensate is passed downstream for further processing via conduit 316. A first liquid bottoms stream is passed from lower portion 306 to a first reboiler 318 via conduit 320 wherein at least a portion of the first liquid bottoms stream is reboiled, thereby forming a first reboiled stream. The first reboiled stream is introduced to lower portion 306 via conduit 322. The remaining portion of the first liquid bottoms stream is removed from the first reboiler 318 via conduit 324 and is charged to a second separation column 326, defining a second separation zone having an upper portion 328, a lower portion 330 and an intermediate portion 332. The remaining portion of the first liquid bottoms stream enters second separation column 326 at the intermediate portion 332. A second vaporous overhead stream is passed from upper portion 328 to a second overhead condenser 334 via conduit 336, wherein at least a portion of the second vaporous overhead stream is condensed, thereby forming a second condensate. At least a portion of the second condensate is refluxed to upper portion 328 via conduit 338. The remaining portion of the second condensate is recovered via conduit 340, thereby forming a DCPD stream. A second liquid bottoms stream passes from lower portion 330 to a second reboiler 342 via conduit 344 wherein at least a portion of the second liquid bottoms stream is reboiled, thereby forming a second reboiled stream. The second reboiled stream is introduced to lower portion 330 via conduit 346. The remaining portion of the second liquid bottoms stream is recovered from second reboiler 342 via conduit 348, thereby forming a fuel oil stream. The following example is provided to further illustrate this invention and is not to be considered as unduly limiting the scope of this invention. EXAMPLE This example illustrates the upgrading of a pyrolysis gasoline stream using the inventive process as described above in the first and third embodiments. A pyrolysis gasoline stream from a storage tank at a chemical plant was charged to a heating zone (a dimerizer) at an inlet temperature of about 246°F, and an outlet temperature of about 271°F, thereby forming a first effluent. The first effluent was then separated into a C 5 diolefin stream and a C 6 + stream in a first separation column (depentanizer). The C 6 + stream was then charged to a second separation column having a lower portion, an upper portion, and an intermediate portion containing structured packing, the intermediate portion having 58 theoretical trays. The point of introduction of the first effluent to the intermediate portion was at about the fifteenth theoretical tray. The first vaporous overhead stream in the upper portion of the second separation column was at a pressure of about 1.2 psia, and a temperature of 189°F. The overhead condenser for the second separation column condensed the first vaporous overhead stream to yield a condensate liquid with a temperature of about 55°F, and provided a reflux stream at a reflux ratio of about 0.30. The reboiler for the second separation column was operated at a temperature of about 227°F. A C 6 - C 9 stream was removed from the condenser for the second separation column and a C 10 + stream was removed from the reboiler for the second separation column. The C 10 + stream was then charged to a third separation column having a lower portion, an upper portion, and an intermediate portion containing structured packing, the intermediate portion having 9 theoretical trays. The point of introduction of the C 10 + stream to the intermediate portion was at about the sixth theoretical tray. The second vaporous overhead stream in the upper portion of the third separation column was at a pressure of about 1.6 psia, and a temperature of 189°F. The overhead condenser for the third separation column condensed the second vaporous overhead stream to yield a condensate liquid with a temperature of about 94°F, and provided a reflux stream with a reflux ratio of about 0.44. The reboiler for the third separation column was operated at a temperature of about 198.5 °F. A DCPD stream was removed from the condenser for the third separation column and a fuel oil stream was removed from the reboiler for the third separation column. The C 6 - C 9 stream from the second separation column was combined with a prefractionated raw gasoline stream (prefrac gasoline) to form a combined stream, and the combined stream was contacted with a hydrogenation catalyst containing 0.75 wt. % palladium (obtained from Engelhard Corporation, Iselin, NJ under product designation E347), in the presence of hydrogen, at a pressure of about 375 psia, in a reactor with an inlet temperature of about 166 °F. The temperature differential across the reactor is controlled by recycling a portion of the effluent of the reactor, which has been cooled by a heat exchanger, to the middle portion of the reactor. The recycle rate is adjusted to maintain an outlet temperature of about 270°F. The partially hydrogenated combined stream at the outlet of the reactor constitutes a second effluent. The second effluent was contacted with a hydrodesulfurization catalyst comprising nickel and molybdenum (obtained from Akzo Nobel NV, Arnhem, NL under product designation KF840), in the presence of hydrogen, at a pressure of about 345 psia, an inlet temperature of about 550°F, and an outlet temperature of about 610°F, thereby producing a BTX stream. Compositional analyses of the pyrolysis gasoline stream, first effluent, C 5 diolefin stream, C 6 - C 9 stream, prefrac. gasoline, DCPD stream, combined stream, second effluent, and BTX stream, as analyzed by gas chromatography and normalized to sum to 100 wt.% or 100 lv%, are presented in the table. From the data in the Table, it is readily apparent that the process for upgrading a hydrocarbon feedstock comprising C 5 olefins, C 5 diolefins, CPD, DCPD and aromatics (BTX) results in the production of a purified DCPD stream (83.72 wt.% DCPD), a purified C 5 diolefin stream (87.41 wt.% C 5 diolefins), and a purified BTX stream (73.05 lv % benzene and toluene). Also, the DCPD stream produced by the inventive process has a Pt/Co color number of 21 which is well below 30, the typical specification for DCPD product streams. Furthermore, the total sulfur of the BTX stream was 99.5 % lower than the total sulfur of the combined stream, and, the bromine number of the BTX stream was 98.0 % lower than the bromine number of the combined stream, indicating a much lower olefin concentration in the BTX stream. Reasonable variations, modifications, and adaptations can be made within the scope of the disclosure and the appended claims without departing from the scope of this invention.

Claims: C L A I M S 1. A process for upgrading hydrocarbons comprising the steps of heating a hydrocarbon feedstock comprising CPD, DCPD, C 5 diolefins, benzene, toluene and xylene in a heating zone to demerize CPD to DCPD; separating out a C 10 + stream and separating said C I0 + stream into a fuel oil stream and a DCPD stream comprising DCPD. 2. A process according to claim 1, comprising the steps of: a) heating a hydrocarbon feedstock comprising CPD, DCPD, C 5 diolefins, benzene, toluene, and xylene in a heating zone, to dimerize CPD to DCPD, thereby forming a first effluent; b) separating said first effluent into a C 6 + stream and a C 5 diolefin stream comprising C 5 diolefins; c) separating said C 6 + stream into a C 6 - C 9 stream and a C 10 + stream; d) separating said C 10 + stream into a fuel oil stream and a DCPD stream comprising DCPD; and e) hydrotreating said C 6 - C 9 stream to thereby form a BTX stream comprising benzene, toluene and xylene. 3. A process in accordance with claim 2, wherein step e) is further characterized to include the steps of: contacting said C 6 - C 9 stream with a hydrogenation catalyst, in a first reaction zone and in the presence of hydrogen, to hydrogenate at least a portion of the olefins, diolefins, alkynes, and styrene contained in said C 6 - C 9 stream, thereby forming a second effluent; and contacting said second effluent with a hydrodesulfurization catalyst, in a second reaction zone and in the presence of hydrogen, to desulfurize at least a portion of the sulfur-containing compounds and to saturate substantially most of the olefinic compounds contained in said second effluent, thereby forming said BTX stream. 4. A process in accordance with claim 3, wherein said hydrogenation catalyst comprises a Group VIII metal selected from the group consisting of iron, cobalt, nickel, ruthenium, rhodium, palladium, osmium, iridium, platinum, and combinations of any two or more thereof. 5. A process in accordance with claim 3, wherein said hydrodesulfurization catalyst comprises a Group VIII metal selected from the group consisting of iron, cobalt, nickel, ruthenium, rhodium, palladium, osmium, iridium, platinum, and combinations of any two or more thereof, and a Group VIB metal selected from the group consisting of chromium, molybdenum, tungsten, and combinations of any two or more thereof. 6. A process in accordance with claim 3, wherein said hydrodesulfurization catalyst comprises nickel and molybdenum. 7. A process in accordance with claim 2, wherein the heating in step a) is conducted at a temperature in the range of from about 100°F to about 450°F. 8. A process in accordance with claim 2, wherein step c) is further characterized to include the steps of: providing a separation column, an overhead condenser, and a reboiler, said separation column defining a separation zone having an upper portion, a lower portion and an intermediate portion, said intermediate portion of said separation zone comprising at least about 50 theoretical trays: removing substantially all of the rust contained in said separation column, said overhead condenser and said reboiler; introducing said C 6 + stream to said intermediate portion of said separation zone; allowing a vaporous overhead stream comprising C 6 - C 9 hydrocarbons, and having a pressure in the range of from about 3.44 kPa to about 20.7 kPa (about 0.5 psia to about 3.0 psia) and a temperature in the range of from about 71.1°C to about 93.3°C (about 160°F to about 200°F), to pass from said upper portion of said separation column to said overhead condenser; condensing at least a portion of said vaporous overhead stream in said overhead condenser thereby forming a condensate which has a temperature in the range of from about 10°C to about 32.2°C (about 50°F to about 90°F); refluxing at least a portion of said condensate from said overhead condenser to said upper portion of said separation zone; allowing a liquid bottoms stream comprising C 10 + hydrocarbons to pass from said lower portion of said separation column to said reboiler; reboiling at least a portion of said liquid bottoms stream in said reboiler at a temperature in the range of from about 98.8°C to about 121.1°C (about 210°F to about 250°F) thereby forming a reboiled stream; introducing said reboiled stream to said lower portion of said separation zone; recovering the remaining portion of said liquid bottoms stream from said reboiler thereby forming said C 10 + stream; and recovering the remaining portion of said condensate from said overhead condenser thereby forming said C 6 -C 9 stream. 9. A process in accordance with claim 2, wherein step d) is further characterized to include the steps of: providing a separation column, an overhead condenser, and a reboiler, said separation column defining a separation zone having an upper portion, a lower portion and an intermediate portion, said intermediate portion of said separation zone comprising at least about 9 theoretical trays: removing substantially all of the rust contained in said separation column, said overhead condenser and said reboiler; introducing said C 10 + stream to said intermediate portion of said separation zone; allowing a vaporous overhead stream comprising DCPD, and having a pressure in the range of from about 0.689 kPa to about 13.78 kPa (about 0.1 psia to about 2.0 psia) and a temperature in the range of from about 71.1°C to about 93.3°C (about 160°F to about 200°F), to pass from said upper portion of said separation zone to said overhead condenser; condensing at least a portion of said vaporous overhead stream in said overhead condenser thereby forming a condensate which has a temperature in the range of from about 26.7°C to about 37.8°C (about 80°F to about 100°F); refluxing at least a portion of said condensate to said upper portion of said separation zone; allowing a liquid bottoms stream to pass from said lower portion of said separation zone to said reboiler; reboiling at least a portion of said liquid bottoms stream in said reboiler at a temperature in the range of from about 87.8°C to about 115.5°C (about 190°F to about 240°F) thereby forming a reboiled stream; introducing said reboiled stream to said lower portion of said separation zone; recovering the remaining portion of said condensate from said overhead condenser thereby forming said DCPD stream comprising DCPD; and recovering the remaining portion of said liquid bottoms stream from said reboiler thereby forming said fuel oil stream. 10. A process according to claim 1, comprising the steps of: a) heating a hydrocarbon feedstock comprising CPD, DCPD, C 5 diolefins, benzene, toluene, and xylene in a heating zone to dimerize CPD to DCPD, thereby forming a first effluent; b) separating said first effluent into a C 5 - C, stream and a C ]0 + stream; c) separating said C 10 + stream into a fuel oil stream and a DCPD stream comprising DCPD; d) contacting said C 5 - C 9 stream with a selective hydrogenation catalyst, in a first reaction zone and in the presence of hydrogen, to hydrogenate at least a portion of the diolefins, alkynes, and styrene contained in said C 5 - C 9 stream, thereby forming a second effluent; e) separating said second effluent into a C 6 - C 9 stream and a C 5 olefin stream comprising C 5 olefins; f) contacting said C 6 - C 9 stream with a hydrodesulfurization catalyst, in a second reaction zone and in the presence of hydrogen, to desulfurize at least a portion of the sulfur-containing compounds contained in said C 6 - C 9 stream and to saturate substantially most of the olefinic compounds contained in said C 6 - C 9 stream, thereby forming a BTX stream comprising benzene, toluene and xylene. 11. A process in accordance with claim 10, wherein said selective hydrogenation catalyst comprises a palladium-containing material selected from the group consisting of palladium metal, palladium oxides, and combinations of any two or more thereof, and a component selected from the group consisting of silver, an alkali-metal halide, and combinations of any two or more thereof. 12. A process in accordance with claim 10, wherein said selective hydrogenation catalyst comprises a palladium-containing material selected from the group consisting of palladium metal, palladium oxides, and combinations of any two or more thereof, and an alkali-metal iodide. 13. A process in accordance with claim 10, wherein said hydrogenation catalyst comprises palladium, silver and potassium fluoride. 14. A process in accordance with claim 10, wherein said selective hydrogenation catalyst comprises a palladium-containing material selected from the group consisting of palladium metal, palladium oxides, and combinations of any two or more thereof, and potassium iodide. 15. A process in accordance with claim 10, wherein said hydrodesulfurization catalyst comprises a Group VIII metal selected from the group consisting of iron, cobalt, nickel, ruthenium, rhodium, palladium, osmium, iridium, platinum, and combinations of any two or more thereof and a group VIB metal selected from the group consisting of chromium, molybdenum, tungsten, and combinations of any two or more thereof. 16. A process in accordance with claim 10, wherein said hydrodesulfurization catalyst comprises nickel and molybdenum. 17. A process in accordance with claim 10, wherein the heating in step a) is conducted at a temperature in the range of from about 37.7°C to about 232°C (about 100°F to about 450°F). 18. A process in accordance with claim 10, wherein step b) is further characterized to include the steps of: providing a separation column, an overhead condenser, and a reboiler, said separation column defining a separation zone having an upper portion, a lower portion and an intermediate portion, said intermediate portion of said separation zone comprising at least about 50 theoretical trays: removing substantially all of the rust contained in said separation column, said overhead condenser and said reboiler; introducing said first effluent to said intermediate portion of said separation zone; allowing a vaporous overhead stream comprising C 5 - C 9 hydrocarbons, and having a pressure in the range of from about 3.45 kPa to about 20.67 kPa (about 0.5 psia to about 3.0 psia) and a temperature in the range of from about 71.1°C to about 93.3°C (about 160°F to about 200°F), to pass from said upper portion of said separation column to said overhead condenser; condensing at least a portion of said vaporous overhead stream in said overhead condenser thereby forming a condensate which has a temperature in the range of from about 10°C to about 32.2°C (about 50°F to about 90°F); refluxing at least a portion of said condensate from said overhead condenser to said upper portion of said separation zone; allowing a liquid bottoms stream comprising C 10 + hydrocarbons to pass from said lower portion of said separation column to said reboiler; reboiling at least a portion of said liquid bottoms stream in said reboiler at a temperature in the range of from about 98.8°C to about 121.1°C (about 210°F to about 250°F) thereby forming a reboiled stream and a remaining portion of said first liquid bottoms stream; introducing said reboiled stream to said lower portion of said separation zone; recovering the remaining portion of said liquid bottoms stream from said reboiler thereby forming said C 10 + stream; and recovering the remaining portion of said condensate from said overhead condenser thereby forming said C 5 -C 9 stream. 19. A process in accordance with claim 10, wherein step c) is further characterized to include the steps of: providing a separation column, an overhead condenser, and a reboiler, said separation column defining a separation zone having an upper portion, a lower portion and an intermediate portion, said intermediate portion of said separation zone comprising at least about 9 theoretical trays: removing substantially all of the rust contained in said separation column, said overhead condenser and said reboiler; introducing said C 10 + stream to said intermediate portion of said separation zone; allowing a vaporous overhead stream comprising DCPD, and having a pressure in the range of from about 0.689 kPa to about 13.78 kPa (about 0.1 psia to about 2.0 psia) and a temperature in the range of from about 71.1°C to about 93.3°C (160°F to about 200°F), to pass from said upper portion of said separation zone to said overhead condenser; condensing at least a portion of said vaporous overhead stream in said overhead condenser thereby forming a condensate which has a temperature in the range of from about 26.7°C to about 37.8°C (about 80°F to about 100°F); refluxing at least a portion of said condensate to said upper portion of said separation zone; allowing a liquid bottoms stream to pass from said lower portion of said separation zone to said reboiler; reboiling at least a portion of said liquid bottoms stream in said reboiler at a temperature in the range of from about 87.8°C to about 115.5°C (about 190°F to about 240°F) thereby forming a reboiled stream; introducing said reboiled stream to said lower portion of said separation zone; recovering the remaining portion of said condensate from said overhead condenser thereby forming said DCPD stream comprising DCPD; and recovering the remaining portion of said liquid bottoms stream from said reboiler thereby forming said fuel oil stream. 20. A process for recovering DCPD from a hydrocarbon feedstock comprising the steps of: a) providing a first separation column, a first overhead condenser, and a first reboiler, said first separation column defining a first separation zone having an upper portion, a lower portion and an intermediate portion, said intermediate portion of said first separation zone comprising at least about 50 theoretical trays; b) providing a second separation column, a second overhead condenser, and a second reboiler, said second separation column defining a second separation zone having an upper portion, a lower portion and an intermediate portion, said intermediate portion of said second separation zone comprising at least about 9 theoretical trays; c) introducing a hydrocarbon feedstock comprising DCPD to said intermediate portion of said first separation zone; d) allowing a first vaporous overhead stream comprising C 9 - hydrocarbons, and having a pressure in the range of from about 3.45 kPa to about 20.67 kPa (about 0.5 psia to about 3.0 psia) and a temperature in the range of from about 71.1°C to about 93.3°C (about 160°F to about 200°F), to pass from said upper portion of said first separation column to said first overhead condenser; e) condensing at least a portion of said first vaporous overhead stream in said first overhead condenser thereby forming a first condensate which has a temperature in the range of from about 10°C to about 32.2°C (about 50°F to about 90°F); f) refluxing at least a portion of said first condensate from said first overhead condenser to said upper portion of said first separation zone; g) allowing a first liquid bottoms stream comprising C 10 + hydrocarbons to pass from said lower portion of said first separation column to said first reboiler; h) reboiling at least a portion of said first liquid bottoms stream in said first reboiler at a temperature in the range of from about 98.8°C to about 121.1°C (about 210°F to about 250°F) thereby forming a first reboiled stream and a remaining portion of said first liquid bottoms stream; i) introducing said first reboiled stream to said lower portion of said first separation zone; j) introducing the remaining portion of said first liquid bottoms stream to said intermediate portion of said second separation zone; k) allowing a second vaporous overhead stream comprising DCPD, and having a pressure in the range of from about 0.689 kPa to about 13.78 kPa (about 0.1 psia to about 2.0 psia) and a temperature in the range of from about 71.1°C to about 93.3°C (about 160°F to about 200°F), to pass from said upper portion of said second separation zone to said second overhead condenser; 1) condensing at least a portion of said second vaporous overhead stream in said second overhead condenser thereby forming a second condensate which has a temperature in the range of from about 26.7°C to about 37.8°C (about 80°F to about 100°F); m) refluxing at least a portion of said second condensate to said upper portion of said second separation zone and thereby forming a remaining portion of said second condensate; n) allowing a second liquid bottoms stream comprising fuel oil to pass from said lower portion of said second separation zone to said second reboiler; o) reboiling at least a portion of said second liquid bottoms stream in said second reboiler at a temperature in the range of from about 87.8°C to about 115.5°C (about 190°F to about 240°F) thereby forming a second reboiled stream; p) introducing said second reboiled stream to said lower portion of said second separation zone; and q) recovering the remaining portion of said second condensate from said second overhead condenser thereby forming a DCPD stream. 21. A process in accordance with claim 20, wherein said intermediate portion of said first separation zone comprises at least about 55 theoretical trays, said pressure of said first vaporous overhead stream in step d) is in the range of from about 3.45 kPa to about 13.78 kPa (about 0.5 psia to about 2.0 psia), said temperature of said first vaporous overhead stream in step d) is in the range of from about 76.6°C to about 93.3°C (about 170°F to about 200°F), said temperature in step h) is in the range of from about 98.8°C to about 115.5°C (about 210°F to about 240°F), said intermediate portion of said second separation zone comprises at least about 10 theoretical trays, said pressure of said second vaporous overhead stream in step k) is in the range of from 1.378 kPa to about 6.89 kPa (about 0.2 psia to about 1.0 psia), said temperature of said second vaporous overhead stream in step k) is in the range of from about 82.2°C to about 93.3°C (about 180°F to about 200°F), and said temperature in step o) is in the range of from about 93.3°C to about 104.4°C (about 200°F to about 220°F). 22. A process in accordance with claim 20, wherein said intermediate portion of said first separation zone comprises at least 60 theoretical trays, said pressure of said first vaporous overhead stream in step d) is in the range of from 6.89 kPa to 10.33 kPa (1.0 psia to 1.5 psia), said temperature of said first vaporous overhead stream in step d) is in the range of from 82.2°C to about 93.3°C (180°F to 200°F), said temperature in step h) is in the range of from about 104.4°C to about 110°C (220°F to 230°F), said intermediate portion of said second separation zone comprises at least 11 theoretical trays, said pressure of said second vaporous overhead stream in step k) is in the range of from 2.06 kPa to 4.12 kPa (0.3 psia to 0.6 psia), said temperature of said second vaporous overhead stream in step k) is in the range of from 87.7°C to about 93.3°C (190°F to 200°F), and said temperature in step o) is in the range of from 93.3°C to about 98.8°C (200°F to 210°F). 23. A process in accordance with claim 20, wherein said hydrocarbon feedstock stream is introduced to said intermediate portion of said first separation zone at a theoretical tray location in the range of from about 10 to about 30. 24. A process in accordance with claim 20, wherein said remaining portion of said first liquid bottoms stream is introduced to said intermediate portion of said second separation zone at a theoretical tray location in the range of from about 2 to about 8. 25. A process in accordance with claim 20, wherein said at least a portion of said first condensate in step f) is refluxed to said upper portion of said first separation zone at a reflux ratio in the range of from about 0.1 to about 1.0. 26. A process in accordance with claim 20, wherein said at least a portion of said second condensate in step m) is refluxed to said upper portion of said second separation zone at a reflux ratio in the range of from about 0.1 to about 1.0. 27. A process in accordance with claim 20, wherein said first separation column, said first overhead condenser, said first reboiler, said second separation column, said second overhead condenser, and said second reboiler are operated in the substantial absence of rust and oxygen. 28. A process in accordance with claim 20, wherein substantially all of the rust contained in said first separation column, said first overhead condenser, said first reboiler, said second separation column, said second overhead condenser, and said second reboiler is removed prior to step c).

Inventors: CHEUNG TIN-TACK PETER, JOHNSON MARVIN M, LASHIER MARK E, OWEN STEVEN A, CHEUNG, TIN-TACK, PETER, JOHNSON, MARVIN, M., LASHIER, MARK, E., OWEN, STEVEN, A.
Applicants: CHEUNG TIN TACK PETER, JOHNSON MARVIN M, LASHIER MARK E, OWEN STEVEN A, PHILLIPS PETROLEUM CO, CHEUNG, TIN-TACK, PETER, JOHNSON, MARVIN, M., LASHIER, MARK, E., OWEN, STEVEN, A., PHILLIPS PETROLEUM COMPANY
Application year: 2000
Main classification: C07C2
IPC codes: C10G7, C10G45, C10G65, C10G67, C10G69