JP6574432B2 - Refinery heavy hydrocarbon upgrade process to petrochemical products - Google Patents

Description

  The present invention relates to an upgrade process of refinery heavy hydrocarbons to petrochemical products.

  European Patent No. EP 1779929 relates to a process for converting a sulfur-containing hydrocarbon feedstock into a form suitable for use in automotive diesel.

  US Patent Application No. 2012/000819 relates to a process for the production of high value-added alkylbenzenes and the catalysts used therein, in which naphthenes are obtained by causing an appropriate hydrocracking reaction without causing unnecessary nuclear hydrogenation. Ring-opening reactions are minimized.

  U.S. Pat. No. 4,943,366 relates to the production of high-octane gasoline by hydrocracking of highly aromatic fractions obtained in a catalytic cracking operation, in which light oil or residual feed is in an FCC (fluid catalytic cracking) unit After being decomposed, the decomposition products are fractionated in a cracking fractionator and a distillation column. The low-boiling fraction is then sent to a hydrotreating apparatus that constitutes the first stage of the hydrocracking apparatus. The hydrotreated circulating oil is then sent to another hydrocracking device that constitutes the second stage of the hydrocracking device, where aromatic saturation continues and ring opening and cracking occur. Occurs and hydrocracking products are formed. After hydrogen separation in the separator, the hydrocracker effluent is fractionated in a distillation column to form a product comprising dry gas, gasoline, middle distillate and bottom fraction.

  International application WO 2007/055488 relates to a process for the preparation of aromatic hydrocarbons and liquefied petroleum gas (LPG) from a hydrocarbon mixture comprising: (a) at least one reaction zone of a hydrocarbon feed mixture and hydrogen. And (b) in the presence of a catalyst, the hydrocarbon feed mixture is subjected to (i) a non-aromatic hydrocarbon compound by hydrocracking and (ii) a dealkylation / alkyl exchange reaction in this reaction zone. Converting to an aromatic hydrocarbon compound rich in benzene, toluene and xylene (BTX); (c) LPG and aromatic hydrocarbons from the reaction product of step (b) by gas-liquid separation and distillation Recovering each of the compounds.

  International application WO 99/22577 relates to low pressure hydrocracking, the process comprising: (a) mixing the liquid feed with hydrogen gas; and (b) fixed bed hydrogenation having at least two catalyst particle packed beds. Hydrocracking the mixture in a cracker to produce a light fraction and a heavy fraction; (c) a portion of the heavy fraction (1) hydrogenating the feedstock to be recycled Sending to a cracker, and (2) recycling the heavy fraction of the effluent, and subjecting to an extraction recycle process comprising.

  U.S. Patent Application No. 2012/205285 relates to a hydroprocessing process for hydrocarbon feeds, the process comprising: (a) contacting the feed with (i) a diluent and (ii) hydrogen. Producing a liquid feed; (b) contacting the liquid feed with a first catalyst in a first treatment zone to produce a first product effluent; and (c) a first. Contacting a second product effluent with a second catalyst in a second treatment zone to produce a second product effluent; (d) recycle used for the diluent in step (a) Recycling a portion of the second product effluent as a product stream, wherein the first treatment zone includes at least two stages, and the first catalyst is a hydrotreating catalyst. The second catalyst is a ring-opening catalyst and the first and second treatment zones are It is completely filled with the reaction zone.

  US Patent Application No. 2012/083639 relates to a process for maximizing the production of high value aromatic compounds using stable crude benzene drawing, which process includes an aromatic reactor effluent containing C5 and C6-C10 cuts. An benzene-rich stream, at least one liquid stream (one of these liquid streams that does not contain benzene includes a C6 fraction that does not contain benzene), and at least one vapor stream that does not contain benzene, Separating into a benzene-rich stream and removing at least a portion of the C5 fraction from the benzene-rich stream.

  U.S. Patent Application No. 2006/287561 discloses a process for producing an aromatic hydrocarbon mixture and liquefied petroleum gas (LPG) from a hydrocarbon mixture, and a process for producing a hydrocarbon feedstock used as feedstock in the foregoing process. , To a process that increases the production of C2-C4 light olefin hydrocarbons.

US Patent Application No. 2007/062848 is at least 20% by weight of one or more aromatics containing at least two fused aromatic rings, substituted or unsubstituted with up to two C1-4 alkyl groups. It relates to the step of hydrocracking a feed containing the compound to produce a product stream comprising at least 35% by weight of a C2-4 alkane mixture. In US Patent Application No. 2007/062848, bitumen from oil sands is fed to a conventional distillation apparatus, and the naphtha stream from the distillation apparatus is fed to a naphtha hydrotreating apparatus. The overhead gas stream is a light gas / light paraffin stream and is fed to the hydrocarbon cracker. The diesel stream from the distillation apparatus is supplied to a diesel hydrotreating apparatus, the diesel oil stream from the distillation apparatus is supplied to a vacuum distillation apparatus, and the vacuum diesel oil stream from the vacuum distillation apparatus is supplied to a diesel oil hydroprocessing apparatus. The light gas stream from the light oil hydrotreater is fed to the hydrocarbon cracker. The hydrotreated vacuum gas oil from the vacuum gas oil hydrotreating apparatus is supplied to the catalytic cracking apparatus. The bottom stream from the vacuum distillation unit is a vacuum (heavy) residue and is sent to a heavy oil pyrolysis unit that produces many streams such as a naphtha stream sent to the naphtha hydrotreater, and the diesel stream is diesel The hydrotreated diesel is generated by being sent to the hydrotreating device, and the light oil stream is supplied to the vacuum gas oil hydrotreating device to obtain the hydrotreated gas oil stream supplied to the catalytic cracking device.
U.S. Pat. No. 4,137,147 discloses ethylene and propylene from packages containing at least linear paraffins and isoparaffins having a distillation point below about 360 ° C. and having at least 4 carbon atoms per molecule. It relates to a method of manufacturing. In the method, the load is subjected to a hydrocracking reaction in the presence of a catalyst in a hydrocracking zone, (b) the effluent from the hydrocracking reaction is sent to a separation zone, a fraction consisting essentially of i) methane and optionally hydrogen from the top of the zone, and (ii) hydrocarbons having 2 and 3 carbon atoms per molecule from the zone, (iii) From the bottom, a fraction consisting essentially of hydrocarbons having at least 4 carbon atoms per molecule is discharged, and (c) consisting essentially of hydrocarbons having 2 and 3 carbon atoms per molecule Only the fraction is sent to the steam cracking zone in the presence of steam to convert at least a portion of the hydrocarbons having 2 and 3 carbon atoms per molecule to monoolefinic hydrocarbons; Obtained from the said 1 minute A fraction consisting essentially of hydrocarbons having at least 4 carbon atoms per unit is sent to a second hydrocracking zone where it is treated in the presence of a catalyst and from the second hydrocracking zone. Waste liquid is sent to the separation zone, on the one hand, hydrocarbons with at least 4 carbon atoms per molecule are discharged, at least part of which is recycled to the second hydrocracking zone, on the other hand A fraction consisting essentially of a mixture of hydrogen, methane and saturated hydrocarbons having 2 and 3 carbon atoms per molecule is discharged; a hydrogen stream and a methane stream are separated from said mixture, And hydrocarbons of the mixture having 3 carbon atoms are essentially recovered from hydrocarbons having 2 and 3 carbon atoms per molecule recovered from the separation zone following the first hydrocracking zone. Na Together with the fraction, it is sent to the steam cracking zone. In this way, at the outlet of the steam cracking zone, 2 and 3 carbons per molecule in addition to a stream of methane and hydrogen and a stream of paraffinic hydrocarbons having 2 and 3 carbon atoms per molecule An olefin having atoms and a product having at least 4 carbon atoms per molecule are obtained.
EP-A-0219195 selectively feeds a hydrocarbon compound onto a catalyst in the presence of hydrogen to selectively hydrogenate the fused bicyclic hydroaromatic hydrocarbon compound, and It relates to a process for converting the feed of hydrocarbon compounds into a hydrocarbon having a lower boiling point and a higher octane number by steam cracking to produce a lower octane product with a lower molecular weight.
WO 2012/071137 relates to a method for preparing a gas cracker feedstock. The method comprises contacting a feed containing one or more paraffins having 4 to 12 carbon atoms with a catalyst at elevated temperatures and pressures, respectively, in the presence of hydrogen; Of paraffins having 4 to 12 carbon atoms with respect to the total mass of paraffins having 4 to 12 carbon atoms, and converting ethane and / or propane to ethane and / or propane. Obtaining a steam cracked gas cracker feedstock containing propane.
US Pat. No. 6,187,984 comprises contacting a feed containing n-butane under reaction conditions suitable for the conversion of n-butane to butenes in the presence of a catalyst. The present invention relates to a method for dehydrogenating n-butane to butenes.
U.S. Patent Application Publication No. 2003/232720 includes dehydrating a dehydrogenable hydrocarbon comprising contacting the dehydrogenable hydrocarbon with a dehydrogenation composite catalyst to obtain a dehydrogenated hydrocarbon. It relates to the method of raw materialization.

  Traditionally, crude oil is processed by distillation into many cuts such as naphtha, light oil and residual oil. Each of these components has many potential uses, such as the production of transportation fuels such as gasoline, diesel and kerosene, or as a feed to some petrochemical products and other processing equipment.

  Light crude oil components, such as naphtha and some light oils, are vaporized by vaporizing the hydrocarbon feed stream, then short residence time (less than 1 second), very high temperatures (750 ° C-900 ° C) in the furnace tube. It can be used for the production of light olefins and monocyclic aromatic compounds by processes such as steam cracking exposed to. In such a process, hydrocarbon molecules in the feed are converted into molecules (such as olefins) that are shorter (on average) and have a lower hydrogen to carbon ratio than the feed molecules. The process also includes hydrogen as a useful by-product and a significant amount of low-value by-products such as methane, C9 + aromatics, condensed aromatic species (including more aromatic rings that share the ends), and , Is generated.

  Typically, heavier (ie, higher boiling) aromatic species, such as residual oil, are further processed in a crude refiner to yield a lighter (distillable) product from crude oil. Maximize. This process involves hydrocracking (where the hydrocracked feed is exposed to a suitable catalyst under conditions that simultaneously add hydrogen to crack some of the feed molecules into shorter hydrocarbon molecules. Etc.). The hydrocracking of heavy refiner streams is typically performed at high pressures and temperatures, so capital costs are high.

  The heavy crude oil component is relatively rich in substituted aromatic species, particularly substituted condensed aromatic species (including multiple aromatic rings sharing an end), and under steam cracking conditions, these materials cause C9 + Heavy by-products such as aromatics and condensed aromatics are produced in significant amounts. Therefore, the results of the conventional combination of crude oil distillation and steam cracking may indicate that the cracking yield of valuable products from heavier components is sufficiently high compared to the value of alternative refinery fuels. As a result, a substantial fraction of crude oil will not be properly processed in the steam cracker.

  Another aspect of the technology discussed above is that even if only light crude components (such as naphtha) are treated with steam cracking, a significant portion of the feed stream is a low-value heavy byproduct (C9 + aromatics). Or a condensed aromatic compound). For typical naphtha and light oils, these heavy by-products may constitute 2-25% of the total product yield (Table VI, page 295, pyrolysis: Theory and Industrial Practice by Lyle F. Albright et al. , Academic Press (1983)). This represents a significant decline in the economic value of expensive naphtha and / or gas oil in low-value materials at the scale of conventional steam crackers, and in the yield of these heavy by-products The capital investment required to upgrade the material to a flow that can produce a significant amount of higher value chemicals (eg, in hydrocracking) is typically not justified. This is partly due to the high capital costs of hydrocracking plants, and as with most petrochemical processes, the capital costs of these devices are typically 0. This is because it increases as it increases to the sixth to 0.7th power. As a result, the capital cost of small-scale hydrocrackers is usually considered too high, and such an investment in a heavy byproduct steam cracking process is not justified.

  Another aspect of conventional hydrocracking of heavy refiner streams such as residual oil is typically performed under compromise conditions selected to achieve the desired overall conversion. That is. Since the feed stream contains a mixture of species with various ranges of ease of cracking, some of the distillable products formed by the hydrocracking of species that are relatively easily hydrocracked will be hydrocracked. It will be further converted under the conditions required for hydrocracking of species that are more difficult to crack. This increases the hydrogen consumption and thermal management difficulties associated with this process, and increases the yield of light molecules such as methane at the expense of more valuable species.

  As a result of this combination of crude oil distillation and steam cracking of lighter distillate components, the steam cracking furnace ensures that the mixed hydrocarbons and steam streams are exposed to these components before exposing them to the high temperatures required to promote pyrolysis. It will typically not be suitable for processing components that contain significant amounts of materials with boiling points above 350 ° C. that are difficult to evaporate completely. When liquid hydrocarbon droplets are present in the hot section of the cracking tube, the coke accumulates rapidly on the tube surface, leading to a decrease in heat transfer and an increase in pressure loss, and ultimately, in the furnace for decoking. Stopping is required, reducing the operation of the disassembly tube. This difficulty prevents a significant portion of the original crude from being processed into light olefins and aromatic species by the steam cracker.

  US Patent Application No. US2009 / 173665 relates to catalysts and processes that increase monocyclic aromatics content of hydrocarbon feedstocks containing polynuclear aromatic compounds, where increasing monocyclic aromatics reduces unwanted compounds This is achieved by increasing the gasoline / diesel yield while providing a means to upgrade hydrocarbons containing significant amounts of polynuclear aromatics.

  UOP's LCO unicracking process or LCO-X process disclosed in International Application No. WO2009 / 008878 uses partial conversion hydrocracking to produce high quality gasoline and diesel feeds in a simple once-through flow scheme. Manufactured. This feedstock is treated on the pretreatment catalyst and then hydrocracked at the same stage. The product is then separated without the need for liquid recycle. The LCO unicracking process can be designed for lower pressure operation where the pressure requirements are somewhat higher than advanced hydroprocessing but much lower than conventional partial conversion and full conversion hydrocracker designs. From the upgraded middle distillate product, a suitable ultra low sulfur diesel (ULSD) formulation is produced. The naphtha product from low pressure hydrocracking of LCO-X is ultra low sulfur and high octane and can be blended directly into an ultra low sulfur gasoline (ULSG) pool.

  US Pat. No. 7,513,988 treats a compound containing multiple fused aromatic rings to saturate at least one ring and then cleaves the resulting saturated ring from the aromatic portion of the compound. , Processes for producing C2-C4 alkane streams and aromatic streams. These processes are used to process heavy oil residues from treated oil sands, tar sands, shale oils or any oil containing a high content of fused ring aromatics to produce a stream suitable for petrochemical production. A hydrocarbon (eg ethylene) (steam) cracker so that a C2-C4 alkane stream is fed to the hydrocarbon cracker using hydrogen from the cracker for saturation and cleavage of compounds containing multiple aromatic rings Or may be integrated with a hydrocarbon cracker (eg, a steam cracker) and an ethylbenzene unit.

  US Patent Application No. US2005 / 0101814 relates to a process for improving the paraffin content of the feed to a steam cracker, which process feed stream containing C5-C9 hydrocarbons including normal C5-C9 paraffins. Passing through a ring-opening reactor comprising a catalyst that operates under conditions to convert aromatic hydrocarbons to naphthenes and a catalyst that operates under conditions to convert naphthenes to paraffins; and generating a second feed stream; Passing at least a portion of the second feed stream through a steam cracker.

  US Pat. No. 7,067,448 relates to a process for producing n-alkanes from mineral oil fractions containing cyclic alkanes, alkenes, cyclic alkenes and / or aromatics and fractions from heat or catalytic conversion plants. More specifically, this notice refers to an aromatics-rich mineral oil fraction treatment process, where the cyclic alkane obtained after hydrogenation of the aromatics has a chain length as short as possible of the packed carbon chain length. Converted to n-alkane.

  As discussed above, the LCO process relates to full conversion hydrocracking of LCO, a monoaromatic and diaromatic compound-containing stream, to naphtha. As a result of this overall conversion hydrocracking, a naphtha that is high naphthenic and low octane naphtha and that needs to be reformed to produce octane necessary for product blending is obtained.

  International Application No. WO2006 / 122275 produces heavy hydrocarbon crude feeds with lower density, lighter, less sulfur content than the original heavy hydrocarbon crude feeds, and produces value-added materials such as olefins and aromatics The process to upgrade to a possible oil, which comprises, inter alia, combining a portion of a heavy hydrocarbon crude with an oil-soluble catalyst to form a reaction mixture; a feed pretreated at a relatively low hydrogen pressure Reacting to form a product stream wherein the first part comprises light oil, the second part comprises heavy crude oil residue, and the third part comprises light hydrocarbon gas; Charging a portion of the stream into a cracker to produce a stream comprising hydrogen and at least one olefin.

  International application WO 2011005476 uses heavy oils, including crude oil, vacuum residue, tar sand, bitumen and vacuum gas oil, using a catalytic hydrotreating pretreatment process, specifically hydrodemetallation (HDM) and The present invention relates to a process in which hydrodesulfurization (HDS) catalyst is sequentially used to improve the efficiency of a subsequent coker refining apparatus.

  US Patent Application No. US2008 / 194900 relates to an olefin process for steam cracking aromatics-containing naphtha streams, which recovers olefin and cracked gasoline streams from steam cracker effluent and hydrogenates the cracked gasoline streams. The C6-C8 stream is recovered therefrom and the naphtha stream containing the aromatic compound is hydrotreated to obtain a naphtha feed, and the C6-C8 stream is removed using the naphtha feed stream in a common aromatic compound extraction unit. Aromatizing to obtain a raffinate stream; and supplying the raffinate stream to a steam cracking furnace.

  International application WO 2008/092232 relates to a process for extracting chemical components from raw materials such as petroleum and natural gas condensates or petrochemical raw materials such as all kinds of naphtha raw materials, which process desulfurizes all kinds of naphtha raw materials. Subjecting it to a yellowing process; separating a C6-C11 hydrocarbon fraction from any kind of desulfurized naphtha feed; and aromatic compounds from the C6-C11 hydrocarbon fraction in an aromatics extractor. Recovering a fraction, an aromatic compound precursor fraction, and a raffinate fraction; converting an aromatic compound precursor in the aromatic compound precursor fraction into an aromatic compound; and Recovering the aromatic compound from the step.

  An object of the present invention is to provide a method for upgrading heavy hydrocarbon feedstocks to aromatic compounds (BTXE) and LPG.

  Another object of the present invention is to provide a process for producing light olefins and aromatic compounds from heavy heavy hydrocarbon feedstocks that yield high yields of aromatic compounds.

  Another object of the present invention is to provide a process for upgrading crude feed to petrochemical products with high carbon utilization and hydrogen uptake.

Therefore, the present invention
(A) supplying a hydrocarbon feed to the ring-opening reaction zone;
(B) Separating the effluent from (a) into a gas stream containing light boiling hydrocarbons, a liquid stream containing naphtha boiling range hydrocarbons, and a liquid stream containing diesel boiling range hydrocarbons. Supplying step;
(C) supplying the liquid stream containing naphtha boiling range hydrocarbons to a hydrocracking device;
(D) separating the reaction product of the hydrocracker in step (c) into an overhead gas stream containing light boiling hydrocarbons and a bottom stream containing BTX (a mixture of benzene, toluene and xylene). ;
(E) after separating the overhead gas stream from the hydrocracker in step (d) and the gas stream from the separator in step (b), preferably from the gas stream, a steam cracker and propane A refinery heavy hydrocarbon to a petrochemical product comprising: supplying to at least one device selected from the group of a dehydrogenator, a butane dehydrogenator, and a combined propane-butane dehydrogenator About the process.

  By combining the ring-opening process with a hydrocracker, so-called gasoline hydrocracker / feed hydrocracker ("GHC / FHC"), In addition to BTXE, fuel will no longer be produced, and only LPG and BTXE will be produced. BTXE can also be obtained directly as a purified stream as all its azeotropic components are decomposed. LPG can be used for steam cracking and / or PDH / BDH. The hydrogen produced there can be used to supply these hydroprocessing steps. If hydrodesulfurization (HDS) is required, hydrodenitrogenation (HDN) can be applied according to catalyst / process requirements. As used herein, “hydrocracking” is used in a generally accepted sense and can therefore be defined as a catalytic cracking process assisted by the presence of high partial pressure hydrogen; for example, Alfke et al. (2007) See The product in this process is a saturated hydrocarbon, and aromatic hydrocarbons contain BTX, depending on reaction conditions such as temperature, pressure and space velocity and catalytic activity.

  As used herein, “LPG” is an acronym well established as “liquefied petroleum gas”. LPG is generally composed of a blend of C3-C4 hydrocarbons, that is, a mixture of C3 and C4 hydrocarbons.

  One of the petroleum products produced by the process of the present invention is BTX. “BTX” herein relates to a mixture of benzene, toluene and xylene. Preferably, the product produced by the process of the present invention further comprises a useful aromatic hydrocarbon such as ethylbenzene. Accordingly, the present invention preferably provides a process for producing a mixture of benzene, toluene, xylene and ethylbenzene ("BTXE"). The product as produced may be a physical mixture of different aromatic hydrocarbons, or may be further separated directly, for example by distillation, to provide a different purified product stream. Such purified product streams may include benzene product streams, toluene product streams, xylene product streams, and / or ethylbenzene product streams. “Naphthene hydrocarbons” or “naphthenes” or “cycloalkanes” are used herein to have established meanings, and thus one or more carbon atom rings in the chemical structure of their molecules. Relates to types of alkanes having

  The liquid effluent from the ring opening process or the total reactor effluent is preferably fed to a hydrocracking unit ("GHC / FHC") after simply separating a heavier circulating stream containing multiple ring components. This greatly simplifies the ring opening process and reduces the overlap in the equipment required. Note that in another embodiment, the liquid effluent is vaporized prior to entering the hydrocracker. Therefore, the feed to the hydrocracking apparatus may be a liquid phase, a gas phase, or a gas-liquid mixed phase. A hydrogen loop with multiple hydrogen addition / injection points can be applied around both devices, ie around the ring-opening reaction zone and the hydrocracking device (“GHC / FHC”). In another embodiment, the naphtha stream or only a portion thereof can be sent to the FHC / GHC reactor, and all heavy material can be recycled and further converted, thereby simplifying the flowchart.

  The process further comprises separating the reaction product of the hydrocracker in step (c) into an overhead gas stream containing light boiling hydrocarbons and a BTX-containing bottom stream. The hydrogen-containing gas stream may be separated from an overhead gas stream containing light boiling hydrocarbons.

  The process preferably comprises supplying an overhead gas stream from the hydrocracker in step (d) and a gas stream from the separator in step (b) to another separator, and the stream thus separated. Supplying to the steam cracking device and the dehydrogenation device.

  In the present invention, the dehydrogenation process is a catalytic process and the steam cracking process is a pyrolysis process.

  In a preferred embodiment, the process comprises a steam cracker and a propane dehydrogenator after separating the overhead stream from the hydrocracker and the gas stream from the separator, preferably after separating the hydrogen-containing stream from these gas streams. And supplying to one or more devices selected from the group of butane dehydrogenators and combined propane-butane dehydrogenators.

  The addition of ring opening allows for processing of heavier feeds compared to direct delivery to the FHC / GHC unit. Further, by adding a separator prior to the ring opening process, the FHC / GHC unit can convert any naphthenic acid in the feed stream boiling in the naphtha range to aromatics / BTX. This method provides a higher BTX yield compared to the ring opening process alone. This is because otherwise, these naphthenic acids can be decomposed in the ring-opening process to produce LPG instead of BTX.

  In a preferred embodiment, the process is carried out in a splitter unit (from which the naphtha boiling range hydrocarbons are fed directly into the hydrocracking unit and its heavy fraction is fed into the ring-opening reaction zone). And a step of pretreating the hydrocarbon feedstock.

  The process preferably comprises a hydrocarbon feedstock with an aromatic extractor (from which an aromatic rich stream is fed into the ring-opening reaction zone, the aromatic extractor being a distillation apparatus type, molecular sieve. And pre-treating within a group selected from the group of types and solvent extractor types.

  In addition to the splitter as described above, the yield on BTX can be further improved by pre-cracking the feed using hydrocracking techniques. Such a preferred process can produce highly naphthenic and aromatic naphtha range materials based on the type of feed that can be processed in the FHC / GHC section, more than if fed directly into the ring opening process. As the naphthenic acid is converted again, BTX can be maximized.

  The hydrogen loop for the three reactors can be optimized for purity, cascade, and pressure level. The heavy unconverted material at the exit of the ring opening reactor is recycled to either the ring opening process or the first hydrocracking step.

  Thus, the process preferably comprises a prehydrocracking apparatus for hydrocarbon feedstock (from which a gas stream comprising LPG is converted into a steam cracker, a propane dehydrogenator, a butane dehydrogenator and a propane-butane combined dehydration. And a heavier hydrocarbon fraction is fed to the ring-opening reaction zone, and a stream containing naphtha boiling range hydrocarbons is fed to the hydrocracking unit. A step of preprocessing within (provided directly).

  In another embodiment, the inventors have found that replacing the first prehydrocracking step with a hydrodealkylation / reforming process results in a high purity BTXE stream. As a result, more BTX can be generated compared to the pre-hydrocracking step embodiment. This is because more “active” aromatics are produced in the first reactor of the modified type, which not only aromatizes the naphthene, but also forms some rings. It must be.

  Thus, the process preferably comprises hydrodealkylation / reforming type equipment of hydrocarbon feedstock (from which a BTXE stream is obtained and a gas stream comprising LPG is fed into a steam cracker, propane dehydrogenator, butane In one or more units selected from the group of dehydrogenators and propane-butane combined dehydrogenators, the heavier hydrocarbon fraction being fed into the ring-opening reaction zone) The method further includes a step of processing.

  The process preferably further comprises the step of feeding a hydrocracker bottom stream, such as a BTX rich stream, to the transalkylation reactor.

  The process also preferably further comprises the step of feeding a liquid stream comprising diesel boiling range hydrocarbons from the separator to the aromatic compound saturator.

  The process preferably provides the hydrocracker with at least one of a gas stream from the separation unit, a gas stream from the hydrodealkylation / reforming type device, and a gas stream from the prehydrocracking unit. Further comprising the step of: In another embodiment, at least one of the stream from the hydrodealkylation / reforming type apparatus and the stream from the prehydrocracking apparatus is sent to the ring-opening reaction zone. Such a flow can be a gas flow.

  The overhead streams from the hydrocracker, the gas stream from the separator, and potentially the gas streams from the prehydrocracker and hydrodealkylation / reforming type equipment are mainly C2 paraffin, C3 paraffin and Can be separated into individual streams containing C4 paraffins, each of which is fed to a specific furnace section of a steam cracker, and the hydrogen-containing stream can be one or more of hydrocrackers, ring-opening reaction zones, etc. Sent to multiple hydrogen consuming process equipment.

  In a preferred embodiment, a portion of the gas stream sent to the steam cracker is sent to the dehydrogenator, but in this case C3 and C4 streams, particularly as a mixed stream of C3 + C4, more preferably C3 It is preferred to send only the -C4 fraction to the dehydrogenator.

  Thus, the method comprises at least selected from the group of steam crackers, butane dehydrogenators, propane dehydrogenators, propane-butane combined dehydrogenators or combinations of these devices to produce a mixed product stream. A combination with one device. This combination of equipment yields a high yield of the desired product, namely olefin and aromatic petrochemical, with a significantly higher percentage of crude oil converted to LPG.

  In a preferred embodiment, the gas stream, for example the overhead gas stream from the hydrocracker in step (d) and the gas stream from the separator in step (b), is separated into one or more streams and hydrogen A stream containing methane is preferably used as a hydrogen source for hydrocracking purposes; a stream containing methane is preferably used as a fuel source; a stream containing ethane is preferably used as a feed for a steam cracker. The stream containing propane is preferably used as the feed for the propane dehydrogenator; the stream containing butane is preferably used as the feed for the butane dehydrogenator; the stream containing C1 or less is preferred Is used as a fuel and / or hydrogen source; a stream containing C3 or less is preferably used as a feed for a propane dehydrogenator, In form, it is also used as feed for the steam cracker; the stream comprising C2-C3 is preferably used as feed for the propane dehydrogenator, but in another embodiment, for the steam cracker The stream comprising C1-C3 is preferably used as a feed for a propane dehydrogenator, but in another embodiment it is also used as a feed for a steam cracker; C1 A stream comprising C4 butane is preferably used as the feed for the butane dehydrogenator; a stream comprising C2-C4 butane is preferably used as the feed for the butane dehydrogenator; a stream comprising C2 or less Is preferably used as feed for the steam cracker; the stream comprising C3-C4 is preferably for propane or butane dehydrogenator, or propane-butane It is used as seen fit feed for the dehydrogenation unit; C4 stream containing less is preferably used as the feed for butane dehydrogenation unit.

  Recovering hydrogen from the reaction product of one or more devices selected from the group of steam crackers, propane dehydrogenators, butane dehydrogenators and propane-butane combined dehydrogenators; Supplying the recovered hydrogen to the hydrocracking apparatus and the ring-opening reaction zone, and in particular, recovering hydrogen from the dehydrogenation apparatus; Feeding to an optional hydrogen consuming device, such as a ring reaction zone.

  The process conditions applied in the ring-opening reaction region are preferably a temperature of 100 ° C. to 500 ° C., a pressure of 2 to 10 MPa, and an amount of hydrogen per 1,000 kg of raw material on the aromatic compound hydrogenation catalyst. The flow obtained is sent to a ring cleavage apparatus with a temperature of 200 ° C. to 600 ° C., a pressure of 1 to 12 MPa, and a hydrogen content of 50 to 200 kg per 1,000 kg of the obtained flow on the ring cleavage catalyst. It is done.

  The “(aromatic compound) ring-opening unit” is a hydrocracking process suitable for the conversion of feeds with boiling points in the kerosene and light oil boiling range relatively rich in aromatic hydrocarbons, depending on LPG and process conditions. And a light distillate (ARO-derived gasoline). Such an aromatic ring opening process (ARO process) is described, for example, in US Pat. No. 7,513,988. Therefore, the ARO process is carried out in the presence of an aromatic compound hydrogenation catalyst under the conditions of a temperature of 300 to 500 ° C., a pressure of 2 to 10 MPa, and a hydrogen content of 10 to 30% by mass (based on the hydrocarbon raw material). And ring cleavage carried out under the conditions of a temperature of 200 to 600 ° C., a pressure of 1 to 12 MPa, and a hydrogen content of 5 to 20 mass% (based on the hydrocarbon raw material) in the presence of a ring cleavage catalyst. Alternatively, the aromatic ring saturation and ring cleavage may be performed in one reactor or in two successive reactors. The aromatic compound hydrogenation catalyst may be a conventional hydrogenation / hydrotreating catalyst, such as a catalyst comprising a mixture of Ni, W and Mo on a refractory support, typically alumina. The ring cleavage catalyst comprises a metal component and a support, preferably composed of Pd, Rh, Ru, Ir, Os, Cu, Co, Ni, Pt, Fe, Zn, Ga, In, Mo, W and V One or more metals selected from the group are included. By adapting the residence time under aromatic ring saturation conditions, towards full saturation and subsequent cleavage of all rings (relatively longer residence time under aromatic ring saturation conditions), or unsaturation of one aromatic ring This process can be guided towards the maintenance of the ring and subsequent cleavage of all rings except one (relatively short residence time under aromatic ring saturation conditions). In the latter case, the ARO process produces a light distillate (“ARO gasoline”) that is relatively rich in hydrocarbon compounds having one aromatic ring.

  The process conditions applied in the separation apparatus are preferably a temperature of 149 ° C. to 288 ° C. and a pressure of 1 MPa to 17.3 MPa.

  As process conditions applied in the hydrocracking apparatus, the reaction temperature is preferably 300 to 580 ° C, preferably 450 to 580 ° C, more preferably 470 to 550 ° C; 5 MPa (gauge pressure), preferably 0.6 to 3 MPa (gauge pressure), particularly preferably 1000 to 2000 kPa (gauge pressure), most preferably 1 to 2 MPa (gauge pressure), and most preferably 1. 2 to 1.6 Mpa (gauge pressure); mass space velocity per unit time (WHSV) is 0.1 to 10 h, preferably 0.2 to 6 h / h, more preferably 0.4 to 2 / h.

  As the process conditions applied in the steam cracker, the reaction temperature is preferably 750 to 900 ° C., the residence time is 50 to 1000 ms, and the pressure is selected in the range of atmospheric pressure to 175 kPa (gauge pressure). .

  A very common process for converting alkanes to olefins is equipped with "steam cracking" as used herein, which is a small, often saturated hydrocarbon. It relates to a petrochemical process that decomposes into unsaturated hydrocarbons (such as ethylene and propylene). In steam cracking, gaseous hydrocarbon feeds (gas cracking) such as ethane, propane, butane or mixtures thereof, or liquid hydrocarbon feeds (liquid cracking) such as naphtha and light oil are diluted with steam, Heated briefly in the absence of oxygen. Typically, the reaction temperature is very high at about 850 ° C., but the reaction only occurs while the residence time is usually as short as 50-500 ms. Preferably, the hydrocarbon compounds ethane, propane and butane are cracked separately and therefore in a dedicated furnace to ensure that they are cracked at optimum conditions. When the decomposition temperature is reached, the quenching oil is used to quench the gas and stop the reaction in the transfer line heat exchanger or in the quenching header. By steam cracking, coke in the form of carbon slowly deposits on the reactor walls. Decoking requires the furnace to be disconnected from the process, after which steam or steam / air mixture is passed through the furnace coil. This converts the hard solid carbon layer into carbon monoxide and carbon dioxide. When this reaction is complete, the furnace is ready for use. The product produced by steam cracking depends on the feed composition and the hydrocarbon to steam ratio, as well as the cracking temperature and furnace residence time. Light hydrocarbon feeds such as ethane, propane, butane or light naphtha provide a lighter polymer grade olefin rich product stream containing ethylene, propylene and butadiene. Even heavier hydrocarbons (full range and heavy naphtha and gas oil fractions) can yield products rich in aromatic hydrocarbons.

In order to separate different hydrocarbon compounds produced by steam cracking, the cracked gas is fed into a fractionation device. Such fractionators are well known in the art and include so-called gasoline fractionators that separate heavy fractions (“carbon black oil”) and middle fractions (“cracked distillate”) from light fractions and gas. obtain. In subsequent quenching towers, the majority of the light fraction ("cracked gasoline" or "pygas") produced by steam cracking may be separated from the gas by liquefying the light fraction. Thereafter, the gas may be subjected to a multistage compression stage to separate the remainder of the light fraction from the gas between the compression stages. Further, it may be removed between the compression stage acid gas (CO ₂ and _H 2 S). In the next step, the gas generated by pyrolysis may be partially liquefied on the stage of the cascade refrigeration system to the extent that only hydrogen remains in the gas phase. Different hydrocarbon compounds may then be separated by simple distillation, where ethylene, propylene and C4 olefins are the most important high value chemicals produced by steam cracking. Methane produced by steam cracking is commonly used as a fuel gas, and hydrogen may be separated and recycled to a hydrogen consuming process such as a hydrocracking process. The acetylene produced by steam cracking is preferably selectively hydrogenated to ethylene. Alkanes contained in the cracked gas may be recycled to the process of converting alkanes to olefins.

  As used herein, “propane dehydrogenation equipment” relates to a petrochemical process equipment that converts a propane feed stream to a product containing propylene and hydrogen. Thus, "butane dehydrogenator" relates to a process device that converts a butane feed stream to C4 olefins. Both lower alkane dehydrogenation processes such as propane and butane are described as lower alkane dehydrogenation processes. Lower alkane dehydrogenation processes are well known in the art and include oxidative hydrogenation processes and non-oxidative dehydrogenation processes. In an oxidative dehydrogenation process, process heating is obtained by partial oxidation of lower alkanes in the feed. In a non-oxidative dehydrogenation process suitable in the context of the present invention, process heating for an endothermic dehydrogenation reaction is obtained from an external heat source such as combustion of fuel gas or high temperature flue gas obtained with steam. For example, in the OOP Oleflex process, propylene is formed by dehydrogenation of propane in the presence of a catalyst comprising platinum supported on alumina in a fluidized bed reactor, and (iso) butane by dehydrogenation of (iso) butane. Butylene (or a mixture thereof) is formed: see, for example, US Pat. No. 4,827,072. In the Uhde STAR process, propylene is formed by dehydrogenation of propane and butylene is formed by dehydrogenation of butane in the presence of a promoted platinum catalyst supported on a zinc-alumina spinel: US Pat. No. 4,926, for example. See 005. The STAR process has recently been improved by applying the principle of oxydehydrogenation. In the second adiabatic zone within the reactor, some of the hydrogen from the intermediate product is selectively converted with the added oxygen to form water. This shifts the thermodynamic equilibrium to higher conversion and achieves higher yields. Further, part of the external heat necessary for the endothermic dehydrogenation reaction is supplied by hydrogen conversion accompanied by heat generation. The Lummus Catofin process uses many fixed bed reactors that operate periodically. The catalyst is activated alumina impregnated with 18-20% by weight of chromium; see, for example, European Patent No. EP 092059A1 and British Patent No. GB2162082A. The Catofin process is durable and can handle impurities that can reduce the action of the platinum catalyst. The product produced in the butane dehydrogenation process depends on the butane feed used and the nature of the butane dehydrogenation process. Also in the Catofin process, butylene is formed by dehydrogenation of butane: see, for example, US Pat. No. 7,622,623.

  The hydrocarbon feedstock in step (a) is shale oil, crude oil, kerosene, diesel, atmospheric pressure light oil (AGO), gas condensate, wax, crude oil mixed naphtha, vacuum gas oil (VGO), vacuum residue, atmospheric residue, Selected from the group of naphtha and pretreated naphtha, or combinations thereof. Other suitable feedstocks are light circulating oil / heavy circulating oil (LCO / HCO), coke naphtha and diesel, FCC naphtha and diesel, and even slurry oil.

  Hereinafter, the present invention will be described in more detail with reference to the accompanying drawings. In the drawings, the same or similar elements are denoted by the same reference numerals.

FIG. 2 is a schematic diagram of an embodiment of the process of the present invention. 4 is another embodiment of the process of the present invention. 4 is another embodiment of the process of the present invention. 4 is another embodiment of the process of the present invention. 4 is another embodiment of the process of the present invention. 4 is another embodiment of the process of the present invention.

  Referring to the process and apparatus shown schematically in FIG. 1, process 101 upgrades refinery heavy hydrocarbons to petrochemical products. The hydrocarbon feed 5 is sent to the ring-opening reaction zone 1 and its effluent 17 produces a gas stream 4 containing LPG, a liquid stream 18 containing naphtha boiling range hydrocarbons and a liquid stream 15 containing diesel boiling range hydrocarbons. Is sent to the separation device 2. A stream 15 comprising diesel boiling range hydrocarbons is preferably recycled to the inlet of the ring-opening reaction zone 1. A stream 18 containing naphtha boiling range hydrocarbons is sent to a hydrocracker 3 that produces an overhead gas stream 9 containing LPG and a bottoms stream 11 containing an aromatic hydrocarbon such as BTX. Streams 4 and 9 are mixed as stream 10 and further processed in a steam cracker and a dehydrogenator selected from the group of a propane dehydrogenator, a butane dehydrogenator and a combined propane-butane dehydrogenator. The In this embodiment, the gas stream 10 is first separated into individual streams 24, 25, 26 by a separation device 20. However, the number of flows is not limited. The light hydrocarbon fraction 24 is sent to a gas steam cracker 22 and its effluent is sent to a further separator 23 which can be equipped with several separators. Streams 25 and 26 are processed in a dehydrogenation section 21 that may comprise several dehydrogenators such as a propane dehydrogenator, a butane dehydrogenator and a combined propane-butane dehydrogenator. The dehydrogenation effluent 28 is sent to a separator 23 where it is separated into individual streams 29, 30 such as olefin-containing streams. However, the number of flows is not limited. In another embodiment, stream 4 (a portion) is sent to hydrocracker 3 that produces an overhead gas stream 9 comprising LPG and a bottom stream 11 comprising an aromatic hydrocarbon such as BTX. Also good.

  In process 201 (see FIG. 2), the hydrocarbon feed 5 is pretreated in a splitter apparatus 5 that produces a stream 16 containing naphtha boiling range hydrocarbons. Stream 16 is sent directly to hydrocracker 3. The effluent of the splitter device 5 containing heavy hydrocarbons is sent to the ring-opening reaction zone 1. In the ring-opening reaction region 1, an effluent stream 17 is generated. Stream 17 is sent to a separator 2 that produces a gas stream 4 containing LPG, a liquid stream 18 containing naphtha boiling range hydrocarbons, and a stream 15 containing diesel boiling range hydrocarbons. A stream 15 comprising diesel boiling range hydrocarbons is preferably recycled to the inlet of the ring-opening reaction zone 1. Stream 18 is further converted in hydrocracker 3 that produces an overhead gas stream 9 comprising LPG and a bottom stream 11 comprising BTX. As mentioned in the discussion of FIG. 1 above, streams 4 and 9 may be mixed as stream 10 for further processing. In another embodiment, stream 4 (a portion) is sent to hydrocracker 3 that produces an overhead gas stream 9 comprising LPG and a bottom stream 11 comprising an aromatic hydrocarbon such as BTX. Also good.

  The yield for BTX can be further improved by providing a prehydrocracking device 6 in addition to the splitter device 5 discussed above in FIG. In the process 301 of FIG. 3, the hydrocarbon feed 5 is prehydrocracked in a prehydrocracking device 6 that produces a gas stream 13 and a bottom stream 8 containing naphtha. Stream 8 is sent directly to hydrocracker 3. The heavy fraction from the prehydrocracking apparatus 6 is sent to the ring-opening reaction zone 1. In the ring-opening reaction zone 1, hydrocarbons from the prehydrocracking device 6 are converted into the effluent 17. The effluent 17 is sent to a separator 2 that produces a gas stream 4 containing LPG, a liquid stream 18 containing naphtha boiling range hydrocarbons, and a stream 15 containing diesel boiling range hydrocarbons. A stream 15 containing diesel boiling range hydrocarbons is recycled to the inlet of the prehydrocracking unit 6. Stream 18 is fed to hydrocracker 3 which produces an overhead gas stream 9 containing LPG and a bottom stream 11 containing BTX. As discussed above in FIG. 1, gas streams 4 and 9 may be mixed as stream 10 for further processing.

  In another embodiment, stream 4 and stream 13 (part of) are in hydrocracker 3 producing an overhead gas stream 9 comprising LPG and a bottom stream 11 comprising an aromatic hydrocarbon such as BTX. May be sent. Also, the stream 13 (a part thereof) may be sent to the ring-opening reaction region 1. In another embodiment, shown in process 4 of FIG. 4, the first hydrocracking step discussed above in FIG. 3 is a hydrodealkylation unit 7 that yields a BTXE stream 12 and a gas stream 14 containing LPG. May be substituted. The heavy fraction from the apparatus 7 is sent to the ring-opening reaction zone 1 to produce an effluent 17. The effluent 17 from the ring-opening reaction zone 1 is sent to a separator 2 that produces a gas stream 4 containing LPG, a liquid stream 18 containing naphtha boiling range hydrocarbons, and a stream 15 containing diesel boiling range hydrocarbons. A stream 15 containing diesel boiling range hydrocarbons is recycled to the inlet of the hydrodealkylation unit 7. Stream 18 is sent to hydrocracker 3 which produces an overhead gas stream 9 containing LPG and a bottom stream 11 containing BTX. The BTXE rich stream generated in the device 7 may be further processed in the hydrocracking device 3. As discussed in FIG. 1 above, gas streams 14, 4 and 9 may be mixed as stream 10 for further processing. In another embodiment (not shown), stream 4 and (part of) stream 14 produce an overhead gas stream 9 comprising LPG and a bottom stream 11 comprising an aromatic hydrocarbon such as BTX. It may be sent to the chemical decomposition apparatus 3. Also, the stream 14 (a part thereof) may be sent to the ring-opening reaction region 1.

  In a preferred embodiment as shown in FIG. 5, in a process 501 for upgrading refinery heavy hydrocarbons to petrochemicals, hydrocarbon feed 5 is sent to ring-opening reaction zone 1 and its effluent 17 is LPG. Is sent to a separator 2 that produces a liquid stream 18 containing naphtha boiling range hydrocarbons, and a liquid stream 15 containing diesel boiling range hydrocarbons. A stream 15 (part) comprising diesel boiling range hydrocarbons may be recycled to the inlet of the ring-opening reaction zone 1. FIG. 5 also shows that stream 15 containing diesel boiling range hydrocarbons is sent as stream 49 to aromatics saturator 50 producing stream 51. The remaining process equipment and flow are similar to those mentioned in FIG. 1 above. In another embodiment, stream 4 (a portion) is sent to hydrocracker 3 that produces an overhead gas stream 9 comprising LPG and a bottom stream 11 comprising an aromatic hydrocarbon such as BTX. Also good.

  In another preferred embodiment, at least a portion of benzene and toluene and the C9-C10 aromatic are introduced into the transalkylation reaction zone. In this embodiment, shown in FIG. 6 as process 601, stream 11 is introduced into transalkylation reaction zone 60 that enhances the production of xylene compounds to produce stream 62. A once-through hydrogen rich gas stream 61 is also introduced into the alkyl exchange reaction zone 60. This gas stream 61 such as hydrogen recovered from the reaction product of the steam cracker or dehydrogenator may be obtained from another hydrogen generator. The operating conditions suitably employed in the alkyl exchange reaction zone are a temperature of 177 ° C. to 525 ° C. and a liquid space velocity per unit time of 0.2 to 10 / h. Any suitable alkyl exchange reaction catalyst may be used in this alkyl exchange reaction zone. Suitable alkyl exchange reaction catalysts include molecular sieves, refractory inorganic oxides, and reduced non-framework weak metals. A suitable molecular sieve is a zeolitic aluminosilicate such as an MFI type zeolite, which may be any one having a ratio of silica to alumina of more than 10 and a pore diameter of 5 to 8 mm. In another embodiment, stream 4 (a portion) is sent to hydrocracker 3 that produces an overhead gas stream 9 comprising LPG and a bottom stream 11 comprising an aromatic hydrocarbon such as BTX. Also good.

(Example)
The process scheme used here conforms to the process shown in FIG. The hydrocarbon feed 5 is fed into the ring-opening reaction zone 1, and the reaction product 17 produced from this reaction zone is separated by the apparatus 2 into an overhead stream 4, a side stream 18 and a bottom stream 15. The side stream 18 is fed into the gasoline hydrocracking (GHC) unit 3 and the reaction products of the GHC unit 3 are mainly in the overhead gas stream 9 containing light components such as C2-C4 paraffin, hydrogen and methane, Separated into stream 11 containing aromatic and non-aromatic hydrocarbon compounds. The overhead gas stream 9 from the gasoline hydrocracker (GHC) unit 3 is mixed with the stream 4 from the unit 2.

  In Case 1 (an example according to the present invention), kerosene as a feed is sent to the ring-opening reaction zone, the side stream is sent to a gasoline hydrocracking (GHC) unit, and the LPG fraction is taken from the overhead of unit 2 To be separated.

  In Case 2 (an embodiment according to the present invention), light vacuum gas oil (LVGO) as a raw material is sent to the ring-opening reaction region, its side stream is sent to a gasoline hydrocracking (GHC) unit, and the LPG fraction is Separated from the overhead of 2.

  Table 1 shows the characteristics of kerosene and LVGO. Table 2 shows the proportion of monocyclic aromatic compounds and aromatic molecules having multiple rings (2+ aromatic compounds) in the feed. Table 3 shows the battery limit product slate (mass% in raw material).

  The above data show that by providing a ring-opening reaction zone and feed gasoline hydrocracking (GHC), polycyclic aromatic molecules can be converted to more valuable monocyclic aromatic compounds and LPG. Yes. BTX can also be obtained from dehydrogenation of naphthene to monocyclic aromatic compounds.

Claims (21)

(A) A hydrocarbon raw material is supplied to the ring-opening reaction zone, and the obtained stream is heated at a temperature of 200 ° C. to 600 ° C., a pressure of 1 to 12 MPa, and the amount of hydrogen per 1,000 kg of the obtained stream on the ring-opening catalyst. Sending to a 50-200 kg ring cleavage device;
(B) Separating the effluent from (a) into a gas stream containing light boiling hydrocarbons, a liquid stream containing naphtha boiling range hydrocarbons, and a liquid stream containing diesel boiling range hydrocarbons. Supplying step;
(C) supplying the liquid stream containing naphtha boiling range hydrocarbons to a hydrocracking device;
(D) separating the reaction product of the hydrocracker in step (c) into an overhead gas stream containing light boiling hydrocarbons and a bottom stream containing BTX (a mixture of benzene, toluene and xylene). ;
(E) a steam cracker, a propane dehydrogenator, a butane dehydrogenator, and an overhead gas stream from the hydrocracker in step (d) and the gas stream from the separator in step (b) Supplying to at least one device selected from the group of combined propane-butane dehydrogenation devices,
The process conditions applied in the ring-opening reaction region of step (a) are as follows: temperature is 100 ° C. to 500 ° C., pressure is 2 to 10 MPa, hydrogen per 1,000 kg of raw material on the aromatic compound hydrogenation catalyst The amount is 50-300kg,
The process conditions applied in the hydrocracking apparatus in step (c) include a reaction temperature of 300 to 580 ° C., a pressure of 0.3 to 5 MPa (gauge pressure), and a mass space velocity per unit time. (WHSV) is 0.1 to 10 / h ,
A refinery heavy hydrocarbon upgrade to petrochemical product further comprising the step of feeding said liquid stream comprising diesel boiling range hydrocarbons from said separator to an aromatic compound saturator .   After separating the overhead gas stream from the hydrocracker in step (d) and the gas stream from the separator in step (b), and a hydrogen-containing stream from the gas stream, a steam cracker and propane dehydration 2. The process of claim 1, wherein the process is fed to at least one device selected from the group of elemental devices, butane dehydrogenators and propane-butane combined dehydrogenators.   Supplying the overhead gas stream from the hydrocracker in step (d) and the gas stream from the separator in step (b) to another separator; The process according to claim 1, further comprising a step of supplying a cracking device and the dehydrogenation device.   The process according to claim 1, wherein the dehydrogenation process is a catalytic process, and the steam cracking process is a thermal cracking process.   The method further comprises pre-treating the hydrocarbon raw material in an aromatic compound extraction apparatus, and supplying an aromatic compound-rich stream from the aromatic compound extraction apparatus into the ring-opening reaction region. The process according to any one of claims 1 to 4.   The process of claim 5, wherein the aromatic compound extraction device is selected from the group of distillation device type, molecular sieve type and solvent extraction device type.   Pre-treating the hydrocarbon feedstock in a splitter apparatus in which a naphtha boiling range hydrocarbon fraction is fed directly into the hydrocracking unit and the heavy fraction is fed into the ring-opening reaction zone. The process according to claim 5 or 6, further comprising:   A heavy hydrocarbon fraction is fed to the ring-opening reaction zone, a stream containing naphtha boiling range hydrocarbons is fed directly to the hydrocracking unit, and a gas stream containing LPG is fed to a steam cracking unit and propane dehydrogenation. Pretreating said hydrocarbon feedstock in a prehydrocracking unit fed to one or more units selected from the group of a unit, a butane dehydrogenation unit and a combined propane-butane dehydrogenation unit The process according to claim 5, further comprising:   A BTXE type stream is obtained, a heavy hydrocarbon fraction is fed to the ring-opening reaction zone, and a gas stream containing LPG is combined with a steam cracker, a propane dehydrogenator, a butane dehydrogenator and a propane-butane combination. Pre-treating said hydrocarbon feedstock in a hydrodealkylation / reformation type device fed to one or more devices selected from the group of dehydrogenation devices A process according to any one of claims 5 to 8.   At least one of the gas stream from the separator of step (b), the gas stream from the hydrodealkylation / reformation type apparatus, and the gas stream from the prehydrocracking apparatus, The process according to claim 1, further comprising a step of supplying the chemical decomposition apparatus.   The process according to any one of claims 3 to 10, further comprising the step of feeding the bottom stream from the hydrocracker to an alkyl exchange reactor. The overhead gas stream from the hydrocracker, the gas stream from the separator in step (b), and optionally the prehydrocracker and the hydrodealkylation / reforming type device. Separating the gas streams into individual streams each mainly comprising C2 paraffin, C3 paraffin and C4 paraffin, and supplying each individual stream to a specific furnace section of the steam cracker. The hydrogen-containing stream is sent to one or more hydrogen consuming process equipment;
The process according to any one of claims 1 to 11 , further comprising the step of supplying only C3-C4 fractions to at least one of the dehydrogenators. 13. Process according to claim 12 , characterized in that the hydrogen consuming process device is the (pre) hydrocracking device or the ring-opening reaction zone. 14. The process according to claim 12 or 13 , further comprising the step of supplying only C3-C4 fractions as separate C3 and C4 streams to at least one of the dehydrogenators. 14. The process according to claim 12 or 13 , further comprising the step of supplying only the C3-C4 fraction as at least one of the dehydrogenators as a mixed stream of C3 + C4. The process according to any one of claims 1 to 15 , wherein the process conditions applied in the separation apparatus are a temperature of 149 ° C to 288 ° C and a pressure of MPa to 17.3 MPa. . The process according to any one of claims 1 to 16 , wherein the reaction temperature is 450 to 580 ° C or 470 to 550 ° C. The pressure is 0.6-3 MPa (gauge pressure), 1000-2000 kPa (gauge pressure), 1-2 MPa (gauge pressure), or 1.2-1.6 MPa (gauge) the process according to any one of claims 1 to 17, characterized in that the pressure). Weight hourly space velocity per unit time (WHSV) is according to any one of claims 1 to 18, characterized in that either a 0.2 to 6 / h, or 0.4 to 2 / h process. The process conditions applied in the steam cracker are characterized in that the reaction temperature is 750 to 900 ° C., the residence time is 50 to 1000 ms, and the pressure is selected from atmospheric pressure to 175 kPa (gauge pressure). the process according to any one of claims 1 to 19. The hydrocarbon feedstock in step (a) is shale oil, crude oil, kerosene, diesel, atmospheric pressure light oil (AGO), gas condensate, wax, crude oil mixed naphtha, reduced pressure gas oil (VGO), reduced pressure residue, atmospheric pressure residue. , Naphtha and pretreated naphtha, light circulating oil / heavy circulating oil (LCO / HCO), coke naphtha and diesel, FCC naphtha and diesel, slurry oil or combinations thereof the process according to any one of claims 1 to 20,.

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