KR20160125503A - Process for upgrading refinery heavy hydrocarbons to petrochemicals - Google Patents

Abstract

The present invention relates to a process for upgrading purified heavy hydrocarbons to petrochemicals, comprising the steps of: (a) feeding a hydrocarbon feedstock to an open loop reaction zone; (b) feeding the effluent from (a) into a separation unit to produce a liquid stream comprising a gaseous stream comprising low boiling hydrocarbons, a liquid stream comprising hydrocarbons in the naphtha boiling range, and hydrocarbons in the diesel boiling range, ; (c) feeding the liquid stream comprising hydrocarbons in the naphtha boiling range to a hydrocracking unit.

Description

PROCESS FOR UPGRADING REFINERY HEAVY HYDROCARBONS TO PETROCHEMICALS BACKGROUND OF THE INVENTION 1. Field of the Invention < RTI ID = 0.0 >

The present invention relates to a process for upgrading purified heavy hydrocarbons to petrochemicals.

EP 1 779 929 relates to a process for converting a hydrocarbon feedstock containing sulfur into a form suitable for use in an automotive diesel.

US patent application 2012/000819 relates to a process for producing alkylbenzenes with a high added value and to catalysts used therefor, which process comprises the steps of subjecting a catalyst to a suitable hydrogenation cracking without causing unnecessary nuclear hydrogenation The reaction causes a minimal naphthene ring opening reaction.

US Pat. No. 4,943,366 relates to the production of octane gasoline by hydrocracking a highly aromatic fraction obtained from catalytic cracking operations wherein the gas oil or residue feed is decomposed in the FCC unit and decomposed The resulting product is fractionated in a cracker fractionator and a distillation column. The low boiling fraction is then transferred to a hydrotreater which forms the first stage hydrocracking unit. The hydrotreated cyclic oil is then transferred to another hydrocracking unit which forms the unit of the second stage and saturation and ring opening and decomposition of the aromatics occurs to form the hydrocracked product. After hydrocracking in the separator, the hydrocracker effluent is fractionated in the distillation column to form a product comprising a dry gas, gasoline, a middle distillate and a bottoms fraction.

WO2007 / 055488 relates to a process for the production of aromatic hydrocarbons and liquefied petroleum gas (LPG) from a hydrocarbon mixture, comprising the steps of: (a) introducing a hydrocarbon feedstock mixture and hydrogen into at least one reaction zone, ; (b) reacting the hydrocarbon feedstock mixture in the presence of a catalyst with a non-aromatic hydrocarbon compound through (i) hydrocracking in the reaction zone, and (ii) dealkylating / transalkylating the benzene, toluene, Converting into an aromatic hydrocarbon compound rich in rhenium (BTX); And (c) recovering LPG and an aromatic hydrocarbon compound from the reaction product of step (b), respectively, through gas-liquid separation and distillation.

WO99 / 22577 relates to low pressure hydrocracking comprising the steps of: (a) mixing a liquid feed with hydrogen gas, (b) mixing the mixture with at least two layers of packed catalyst particles Hydrocracking in a hydrocracker to produce a harder and heavier fraction; (c) a portion of the heavier fraction is subjected to an extinction recycle process comprising the following steps: (1) transferring the material to be refluxed to the hydrocracker and (2) refluxing the heavier fraction of the effluent.

US patent application 2012/205285 relates to a process for hydroprocessing a hydrocarbon feed comprising: (a) contacting the feed with (i) a diluent and (ii) hydrogen to produce a liquid feed; (b) contacting the liquid feed with a first catalyst in a first treatment zone to produce a first product effluent; (c) contacting the first product effluent with a second catalyst in a second treatment zone to produce a second product effluent; And (d) refluxing a portion of the second product effluent as reflux stream for use in the diluent in step (a), wherein the second treatment zone comprises at least two stages, wherein the first catalyst Is a hydrotreating catalyst, the second catalyst is an open catalyst, and the first and second treatment zones are liquid-full reaction zones.

US patent application 2012/083639 relates to a process for maximizing high-value aromatic production using stabilized crude benzene withdrawal, wherein the process comprises a C5-fraction and a C6-C10 fraction Separating the aromatic reactor effluent into a benzene-rich stream and at least one vapor stream depleted in benzene and at least one liquid stream, wherein the one liquid stream depressurized with benzene is a benzene depleted C6- And removing at least a portion of the C5-fraction from the benzene-rich stream.

US patent application 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 that can be used as feedstock in the process of the former, -C4 < / RTI > light olefin hydrocarbons.

US patent application 2007/062848 discloses a composition comprising at least 20% by weight of at least one aromatic compound containing at least two fused aromatic rings (the compound is substituted or unsubstituted by up to two C 1-4 alkyl radicals) Hydrocracking the feed to produce a product stream comprising at least 35% by weight of a mixture of C2-4 alkanes. According to US patent application 2007/062848, bitumen from an oil sand is fed to a conventional distillation unit and the naphtha stream from the distillation unit is fed to a naphtha hydrotreater unit. The overhead gas stream is a light gas / hard paraffin stream and is fed to the hydrocarbon cracker. The diesel stream from the distillation unit is fed to a diesel hydrotreater unit, the gas oil stream from the distillation unit is fed to a vacuum distillation unit, and the vacuum gas oil stream from the vacuum distillation unit is fed to a gas oil hydrotreater. The light gas stream from the gas oil hydrotreater is fed to a hydrocarbon cracker. The hydrogenated vacuum gas oil from the vacuum gas oil hydrotreater is fed into a catalytic cracker unit. The bottoms stream from the vacuum distillation unit is a vacuum (heavy) residue and is sent to a delayed cocker producing a number of streams, such as a naphtha stream sent to the naphtha hydrotreater unit, and the diesel stream is sent to the diesel hydrogenation unit To produce a hydrotreated diesel and the gas oil stream is fed to a vacuum gas oil hydrotreater to produce a hydrotreated gas oil stream fed to the catalytic cracker unit.

Typically, the crude oil is treated by distillation with a number of cuts, such as naphtha, gas oil, and residues. Each of these cuts has many potential uses, such as to produce trasportation fuel such as gasoline, diesel and kerosene, or as a feed to some petrochemicals and other processing units.

The light crude cuts, such as naphtha and some gas oils, are heated to a very high temperature (750 DEG C to 900 DEG C) in a furnace (reactor) tube for a short period of residence time Can be used to produce light olefins and single ring aromatic compounds through processes such as steam cracking, which are diluted with water vapor. In this process, the hydrocarbon molecules in the feed are transformed into molecules (e.g., olefins) that have (on average) a ratio of hydrogen to shorter molecules and lower carbons as compared to the feed molecules. This process also provides a significant amount of lower value co-products such as hydrogen and methane and C9 + aromatic and condensed aromatic species (containing two or more aromatic rings that share an edge) as useful by- product).

Typically, heavier (or higher boiling point) aromatic species, such as residues, are further processed in the refinery to maximize the yield of harder (distillable) products from crude oil. This treatment can be carried out by a process such as hydrocracking, in which the hydrocracker feed is exposed to a suitable catalyst under conditions such that some fraction of the feed molecule is broken with shorter hydrocarbon molecules with simultaneous addition of hydrogen. The heavy refinery stream hydrocracking is typically carried out at high pressures and temperatures and thus has a high capital cost.

Heavier crude cuts are rich in relatively substituted aromatic species, particularly substituted condensed aromatic species (containing two or more aromatic rings that share an edge), and under water vapor cracking conditions, these materials contain significant amounts of heavy by- For example C9 + aromatics and condensed aromatics. Thus, the result of a conventional combination of crude oil distillation and steam cracking is that the decomposition yield of the valuable product from the heavier cut is not considered to be sufficiently high compared to the alternative refinery fuel value, The crude oil is preferably not treated through a steam cracker.

Another aspect of the techniques discussed above is that even though light cycle oil cuts (e.g., naphtha) are treated through steam cracking, a significant fraction of the feed stream is consumed at low cost, such as C9 + aromatic and condensed aromatics (low value) heavy by-products. Along with typical naphtha and gas oils, these heavy by-products may be composed of total product yields of 2 to 25% (Table VI, page 295, Pyrolysis: Theory and Industrial Practice by Lyle F. Albright et al, Academic Press, 1983) . This represents a significant financial downgrade of costly naphtha and / or gas oils at lower values of the substance on the scale of conventional steam crackers, while the yield of these heavy byproducts typically ranges from It does not justify capital investment required to up-grade to a stream that may produce a significant amount of more expensive chemicals (e.g., by hydrocracking). This is partly because hydrocracking plants have high capital costs and, in most petrochemical processes, the capital costs of these units are scaled to the throughput typically raised to a power of 0.6 or 0.7 All. As a result, the capital cost of the small hydrocracking unit is usually too high to justify an investment to treat the steam cracker heavy by-product.

Other aspects of conventional hydrocracking of heavy purification streams such as residues are typically carried out under selected compromise conditions to achieve the desired overall conversion. Because the feed stream contains a mixture of species with ease of various digestion, it is relatively easy to hydrolyse the hydrocracked species so that some fraction of the distillable product formed by hydrogenolysis decomposes the more difficult hydrocracking species To be further switched under the necessary conditions. This increases the difficulty of thermal management associated with hydrogen consumption and processing, and also increases the yield of hard molecules such as methane at the expense of more valuable species.

The result of this combination of steam cracking and crude distillation of harder distillate cuts is that the steam cracking furnace is typically not suitable for the treatment of cuts containing significant quantities of material with a boiling point greater than < RTI ID = 0.0 > This is because it is difficult to ensure complete evaporation of these cuts before exposing mixed hydrocarbons and steam streams to the high temperatures required to promote pyrolysis. If droplets of liquid hydrocarbons are present in the hot zone of the cracking tube, the coke will quickly settle on the furnace surface, which reduces heat transfer, increases pressure drop, and ultimately decoking reducing the operation of the decomposition pipe which requires shut-down of the pipe for decoking. Because of this difficulty, a significant proportion of the original crude oil can not be treated with light olefins and aromatics through steam crackers.

US2009 / 173665 relates to processes and catalysts for increasing the monoaromatic content of hydrocarbon feedstocks comprising polynuclear aromatics, wherein the increase of the monoaromatic can be achieved with an increase in gasoline / diesel yield, While providing a route for upgrading hydrocarbons containing significant amounts of polynuclear aromatics.

The LCO-X process or LCO unicracking of UOP, disclosed in WO2009 / 008878, uses fractional hydrogenolysis to convert high quality gasoline and diesel stock into a single once-through flow scheme, . The feedstock is treated on a pre-treatment catalyst and then hydrocracked in the same step. The product is then separated without the need for liquid refluxing. The LCO unicracking process can be designed for lower pressure operation, which means that the pressure demand is somewhat higher than the severe hydrogenation treatment but is significantly lower than conventional partial conversion and complete conversion hydrocracking unit designs. The upgraded mid-distillation product produces an appropriate ultra-low sulfur diesel (ULSD) blending component. The naphtha product from the LCO-X low-pressure hydrocracker can be blended directly into ultra-low sulfur gasoline (ULSG) pollen with ultra-low sulfur and high octane.

US 7,513,988 relates to a process for treating a compound comprising two or more fused aromatic rings to saturate at least one ring and subsequently cleaving the resulting saturated ring from the aromatic moiety of the compound to produce a C2-C4 alkane stream and an aromatic stream will be. This process is advantageous in that the hydrogen from the cracker is hydrocarbons (e.g., ethylene) (water vapor) so that it can be used to saturate and cut compounds containing two or more aromatic rings and to feed the C2-C4 alkane stream to the hydrocarbon cracker. Or may be incorporated with a hydrocarbon cracker (e.g., steam cracker) and an ethylbenzene unit, which may be a processing oil sand, tar sand, shale oil, or any oil with a high content of fused ring aromatics To produce a stream suitable for the petrochemical product.

US 2005/101814 relates to a process for increasing the paraffin content of a feedstock to a steam cracking unit wherein the feed stream comprising C5 is passed through a C9 containing C5 through a C9 normal paraffin to a ring opening reactor Wherein the ring opening reactor comprises a catalyst operated under conditions for converting an aromatic hydrocarbon to naphthene and a catalyst operated under conditions for converting naphthene to paraffin and producing a second feed stream; And delivering at least a portion of the second feed stream to the steam cracking unit.

US 7,067,448 relates to processes for the production of n-alkanes from mineral oil fractions and fractions from thermal or contact conversion plants containing cyclic alkanes, alkenes, cyclic alkenes and / or aromatics. More specifically, the publication discloses a process for treating an aromatic compound-rich mineral oil fraction, wherein the cyclic alkane obtained after the hydrogenation of the aromatic compound is converted to an n-alkane having a chain length less than that of the possibly filled carbon.

The LCO-process discussed above relates to the complete conversion hydrocracking of LCO to naphtha, and LCO is a mono-aromatic and di-aromatic containing stream. The result of the complete conversion hydrocracking is very naphthenic and the low octane naphtha must be obtained and reformed to produce the octane required for product blending.

WO2006 / 122275 describes a process for upgrading heavy hydrocarbon crude oil feedstocks to oils that are less dense or more rigid and contain less sulfur than the original heavy hydrocarbon crude oil feedstock and produce value-added materials such as olefins and aromatics Wherein the process comprises the steps of combining some heavy hydrocarbon crude oil with an oil soluble catalyst to form a reaction mixture, reacting the pretreated feedstock under relatively low hydrogen pressure to produce a product stream Wherein the product stream of the first portion comprises a light oil, the product stream of the second portion comprises a heavy crude residue, the product stream of the third portion comprises a light hydrocarbon gas, and a portion Lt; RTI ID = 0.0 > hydrogen < / RTI > and at least one olefin ≪ / RTI >

WO2011005476 discloses a process for the continuous use of hydrodemetallization (HDM) and hydrodesulfurization (HDS) to improve the efficiency of subsequent coker purification, especially using a catalytic hydrotreating pre-treatment process , Heavy oil containing crude oil, vacuum residues, tar sand, bitumen and vacuum gas oil.

US 2008/194900 relates to an olefin process for steam cracking an aromatic containing naphtha stream comprising recovering an olefin and pyrolysis gasoline stream from a steam cracking furnace effluent, hydrogenating the pyrolysis gasoline stream and recovering a C6-C8 stream , Hydrotreating the aromatic containing naphtha stream to obtain the naphthafide, derraining the C6-C8 stream with the naphthafide stream in a normal aromatic extraction unit to obtain a raffinate stream; And feeding the raffinate stream to the steam cracking furnace.

WO2008 / 092232 relates to a process for the extraction of chemical components from a feedstock, such as petroleum, natural gas condensate or a petrochemical feedstock, for example a full range of naphtha feedstock, comprising the following steps: Separating the C6 to C11 hydrocarbon fraction from the naphtha feedstock in the entire range of the desulfurization, removing the aromatic fraction from the C6 to C11 hydrocarbon fraction in the aromatic extraction unit, the aromatic precursor fraction and the raffinate fraction Recovering the aromatics from the aromatic extraction unit, converting the aromatic precursor in the aromatic precursor fraction to aromatics, and recovering the aromatics from the step in the aromatic extraction unit.

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

It is a further object of the present invention to provide a process for producing light olefins and aromatics from heavy hydrocarbon feedstocks where high yields of aromatics can be obtained.

It is a further object of the present invention to provide a process for upgrading crude oil feedstocks to petrochemicals with high carbon efficiency and hydrogen integration.

The present invention therefore relates to a process for upgrading purified heavy hydrocarbons to petrochemicals, comprising the following steps:

(a) feeding a hydrocarbon feedstock to an open loop reaction zone;

(b) feeding the effluent from (a) into a separation unit for producing a liquid stream comprising a gaseous stream comprising low boiling hydrocarbons, a liquid stream comprising hydrocarbons in the naphtha boiling range, and a hydrocarbon in the boiling range of the diesel boiling point ;

(c) feeding the liquid stream comprising hydrocarbons in the naphtha boiling range to a hydrocracking unit;

(d) separating the reaction product of the hydrocracking unit of step (c) into BTX (a mixture of benzene, toluene and xylene) comprising a top gas stream comprising a low boiling point hydrocarbon and a bottoms stream,

(e) separating the overhead gas stream from the hydrocracking unit of step (d) and the gas stream from the separate unit of step (b), preferably from the gas stream, Butane dehydrogenation unit, and a combined propane-butane dehydrogenation unit.

The present inventors have found that by combining the ring opening process with a hydrocracking unit, that is, by a so-called gasoline hydrocracking unit / feed hydrocracking unit ("GHC / FHC"), the overall process is no longer subjected to LPG and BTXE In addition, it produces only LPG and BTXE without generating fuel. The latter may also be obtained directly as a refinery stream when all the co-boilers of BTXE are decomposed. LPG can be used in steam cracking and / or PDH / BDH. If necessary, hydrodesulfurization (HDS), hydrogenated dinitration (HDN) can be applied according to catalyst / process requirements. The term " hydrocracking "may be defined as a catalytic cracking process assisted by the presence of a partial pressure of hydrogen which is used herein in its generally accepted sense and which accordingly rises; See, for example, Alfke et al. (2007). The product of this process is a saturated hydrocarbon and depends on the reaction conditions, such as temperature, pressure and space velocity, and on the aromatic hydrocarbons including the catalytic activity, BTX.

The term "LPG" as used herein refers to a well-established acronym for the term " liquefied petroleum gas ". LPG generally consists of a blend of C3-C4 hydrocarbons, i.e. a mixture of C3 and C4 hydrocarbons.

One of the petrochemical products produced in the process of the present invention is BTX. The term "BTX" as used herein relates to a mixture of benzene, toluene and xylene. Preferably, the product produced in the process of the present invention comprises additional useful aromatic hydrocarbons such as ethylbenzene. Thus, the present invention preferably provides a process for producing a mixture ("BTXE") of benzene, toluene xylene and ethylbenzene. The resulting product may be a physical mixture of different aromatic hydrocarbons or may be subjected to further separation directly, for example by distillation, to provide different purified product streams. The purified product stream may comprise a benzene product stream, a toluene product stream, a xylene product stream, and / or an ethylbenzene product stream. The term "naphthenic hydrocarbon" or "naphthenes" or "cycloalkane" is used herein in its articulated sense, Lt; RTI ID = 0.0 > atoms. ≪ / RTI >

The liquid effluent or even the complete reactor effluent from the ring opening process is preferably separated from the heavier reflux stream containing the multicyclic components and then fed to the hydrocracking unit ("GHC / FHC"). This greatly simplifies the ring opening process and reduces the excess in the required separation unit. Note that in another embodiment the liquid effluent is evaporated prior to entering the hydrocracking unit. The feed to the hydrocracking unit may thus be liquid, vaporous or mixed vapor-liquid. The hydrogen loop can be applied around both units, i.e., the ring open reaction zone and the hydrocracking unit ("GHC / FHC"), with the addition of hydrogen and multiple additions. According to another embodiment, only the naphtha stream, or a portion thereof, is sent to the FHC / GHC reaction zone, presumably all the heavier materials are refluxed and further converted, thereby simplifying the flow chart.

The process further comprises separating the reaction product of the hydrocracking unit of step (c) into BTX comprising a tower gas stream comprising a low boiling point hydrocarbon and a bottoms stream. The hydrogen-containing gas stream may be separated from the top gas stream containing low boiling hydrocarbons.

The process preferably comprises the steps of feeding the overhead gas stream from the hydrocracking unit of step (d) and the gaseous stream from the separate unit of step (b) to another separation unit and thus to separate the separated stream from the steam cracking unit And supplying the dehydrogenation unit (s) to the dehydrogenation unit (s).

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

According to a preferred embodiment, the process comprises separating the overhead stream from the hydrocracking unit and the gas stream from the separating unit, preferably the hydrogen-containing stream from the gas stream, and then passing it through a steam cracking unit and a propane dehydrogenating unit, To at least one unit selected from the group of dehydrogenation units and combined propane-butane dehydrogenation units.

By adding a ring opening, it is possible to process heavier feeds and send them directly to the FHC / GHC unit. Also, the addition of a separation unit prior to the ring opening process allows the FHC / GHC unit to convert any naphthene in the boiling feed stream to aromatics / BTX in the naphtha range. This approach can result in higher BTX yields compared to the ring openings, or else these naphthes will decompose in the ring opening process and produce LPG rather than BTX.

According to a preferred embodiment, the process further comprises pre-treating the hydrocarbon feedstock in a splitter unit, wherein hydrocarbons in the boiling range of the naphtha from the splitter unit are fed directly to the hydrocracking unit, Its heavier fraction is fed into the ring opening reaction zone.

The process preferably further comprises the step of pretreating the hydrocarbon feedstock in an aromatic extraction unit from which the aromatic rich stream is fed to the reaction zone for ring opening and the aromatic extraction unit is fed to the distillation unit The type of molecular sieve, and the type of solvent extraction unit.

In addition to the splitter mentioned above, the yield towards BTX can be further improved by "pre-cracking" the feed using hydrocracking techniques. This preferred process can produce materials in the naphtha range that are naphthenic aromatic, based on the type of feed material that can be processed in the FHC / GHC region to produce maximum BTX, This is because much more naphthenes are converted back to BTX compared to direct feeding into the ring opening process.

The hydrogen loop for the three reaction zones can be optimized for purity, cascade, pressure level. At the outlet of the loop-opening reactor, the heavily unconverted material can be recycled to the ring-opening process or the first hydrocracking stage.

Thus, the process preferably further comprises pre-treating the hydrocarbon feedstock in a pre-hydrocracking unit, wherein the gas stream comprising LPG from the hydrocracking unit comprises a steam cracking unit, Propane dehydrogenation unit, butane dehydrogenation unit and combined propane-butane dehydrogenation unit, its heavier hydrocarbon fraction is fed into the ring opening reaction zone, and the naphtha boiling range The stream containing the hydrocarbons is fed directly to the hydrocracking unit.

The inventors have found in another embodiment that the first hydrolysis decomposition step can be replaced by a hydrogenated dealkylation / reforming process and produces a high purity BTXE stream. As a result, much more BTX can be produced as compared to the implementation of the hydrolysis decomposition step, which is due to the additional aromatic production 'active' in the first reactor in the reformed form, As well as some additional ring formation must occur.

Thus, the process preferably further comprises the step of pretreating the hydrocarbon feedstock in a hydrodealkylation / reforming type unit, wherein a BTXE stream is obtained from the hydrogenated dealkylation / reforming unit and the gas comprising LPG The stream is fed to at least one unit selected from a steam cracking unit, a propane dehydrogenating unit, a butane dehydrogenating unit and a combined propane-butane dehydrogenating unit, and its heavier hydrocarbon fraction is fed into the loop open reaction zone.

The process preferably further comprises feeding a BTX rich stream of a bottoms stream, for example a hydrocracking unit, to the transalkylation unit.

Additionally, the process preferably further comprises feeding a liquid stream comprising a hydrocarbon ranging from the boiling range of the diesel from the separation unit to the aromatic saturation unit.

The process preferably further comprises feeding at least one of a gaseous stream from the separation unit, a gaseous stream from the hydrogenated dealkylation / reformate type unit and a gaseous stream from the hydrocracking unit to a hydrocracking unit. According to another embodiment, at least one of the stream from the hydrogenated dealkylation / reforming unit and the stream from the hydrolysis decomposition unit is directed to the reaction zone for ring opening. Such a stream may be a gas stream.

The overhead stream from the hydrocracking unit, the gaseous stream from the separation unit, and possibly the gaseous stream from the hydrolysis cracking unit and the hydrodealkylation / reforming unit can be separated into individual streams, each stream comprising C2 paraffin, C3 Paraffin and C4 paraffin respectively and feeds each individual stream to a specific furnace region of the steam cracker unit, the hydrogen containing stream comprising at least one hydrogen consuming process unit, for example a hydrocracking unit, and a reaction zone Lt; / RTI >

According to a preferred embodiment, the gas stream sent to the steam cracker unit is partly sent to the dehydrogenating unit, and only the C3-C4 fraction is treated as a particularly separate C3 and C4 stream, more preferably the combined C3 + C4 stream To the dehydrogenation unit.

Accordingly, the process comprises combining at least one of a steam cracker unit, a butane dehydrogenation unit, a propane dehydrogenation unit and a combined propane-butane dehydrogenation unit or a combination of these units to produce a mixed product stream Unit combination. The combination of these units provides high yields of the desired products, namely olefins and aromatic petrochemicals, and the fraction of crude oil converted to LPG is significantly increased.

According to a preferred embodiment, the gas stream, for example the top gas stream from the hydrocracking unit of step (d) and the gas stream from the separation unit of step (b) are separated into one or more streams, Is preferably used as a source of hydrogen for hydrocracking purposes and the stream comprising methane is preferably used as the fuel source and the stream comprising ethane is preferably used as a feed for the steam cracking unit, The stream is preferably used as a feed for the propane dehydrogenation unit and the stream comprising butane is preferably used as feed for the butane dehydrogenation unit and the stream comprising C1-minus is preferably used as the fuel source and / Or a source of hydrogen, and a stream containing C3- Preferably used as feed for the propane dehydrogenation unit but according to another embodiment is also used as feed for the steam cracking unit and the stream comprising C2-C3 is preferably used as feed for the propane dehydrogenation unit, According to another embodiment, it is also used as a feed for the steam cracking unit, and the stream comprising C1-C3 is preferably used as a feed for the propane dehydrogenation unit, but according to another embodiment, Feed stream, the stream comprising C1-C4 butane is preferably used as feed for the butane dehydrogenation unit, the stream comprising C2-C4 butane is preferably used as feed for the butane dehydrogenation unit, C2- The stream containing minus is preferably used as a feed for the steam cracking unit And the stream comprising C3-C4 is preferably used as a feed for the propane or butane dehydrogenation unit or as a feed for the combined propane and butane dehydrogenation unit and the C4-minus stream is preferably a butane dehydration It is used as a feed for fire extinguishing units.

The process comprises recovering hydrogen from the reaction product of at least one unit selected from the group of a steam cracking unit, a propane dehydrogenating unit, a butane dehydrogenating unit and a combined propane-butane dehydrogenating unit, and thereby hydrogenating the recovered hydrogen Further comprising feeding the recovered hydrogen from the dehydrogenation unit and the recovered hydrogen to any hydrogen consuming unit, such as a hydrocracking unit and an open loop To the reaction zone for < RTI ID = 0.0 >

The prevailing process conditions in the reaction zone for the ring opening are carried out in the presence of 50 to 300 kg of hydrogen per 1000 kg of feedstock on the aromatic hydrogenation catalyst, preferably at a temperature of 100 ° C to 500 ° C and a pressure of 2 to 10 MPa And the resulting stream is transferred to the ring-cleavage unit at a temperature of 200 ° C to 600 ° C and a pressure of 1 to 12 MPa, with 50 to 200 kg of hydrogen per 1000 kg of the produced stream on the ring-cut catalyst.

The term "(aromatic) loop opening unit" is intended to cover a relatively rich feed of aromatic hydrocarbons with a boiling point in kerosene and gas oil boiling range to produce a light distillate (ARO-derived gasoline) according to LPG and process conditions ≪ RTI ID = 0.0 > a < / RTI > hydrocracking process. This aromatic ring opening process (ARO process) is described, for example, in US 7,513,988. Thus, the ARO process can be carried out in the presence of an aromatic hydrogenation catalyst (with respect to the hydrocarbon feedstock), with 10-30 wt% of hydrogen, at a pressure of 2-10 MPa, at a temperature of 300-500 DEG C for aromatic ring saturation and In the presence of a ring cleavage catalyst (with respect to the hydrocarbon feedstock), at a pressure of 1-12 MPa, at a temperature of 200-600 ° C, with 5-20 wt% of hydrogen, The aromatic cyclization and ring cleavage may be carried out in one reactor or two successive reactors. The aromatic hydrogenation catalyst may be a conventional hydrogenation / hydrotreating catalyst, such as a catalyst comprising a refractory support, typically a mixture of Ni, W and Mo on alumina. The ring-cleaving catalyst comprises a metal component and a support, and preferably a group consisting of Pd, Rh, Ru, Ir, Os, Cu, Co, Ni, Pt, Fe, Zn, Ga, In, Mo, ≪ / RTI > By adapting the residence time under aromatic cyclic saturation conditions, the process can be carried out either to complete saturation and to subsequent cleavage of all rings (relatively long residence time under saturated conditions of the aromatic rings), or to keep one aromatic ring unsaturated (Relative short residence time under aromatic cyclic saturation conditions) to subsequent cleavage of all rings except one. In the latter case, the ARO process produces a hard distillate ("ARO-gasoline"), which is relatively rich in hydrocarbon compounds having one aromatic ring.

The general process conditions in the separation unit preferably include a temperature of 149 DEG C to 288 DEG C and a pressure of 1 to 17.3 MPa.

Typical process conditions in the hydrocracking unit are a reaction temperature of preferably 300-580 ° C, preferably 450-580 ° C, more preferably 470-550 ° C, a pressure of 0.3-5 MPa gauge pressure, preferably 0.6-3 MPa gauge pressure, particularly preferably 1000-2000 kPa gauge pressure, most preferably 1-2 MPa gauge pressure, most preferably 1.2-1.6 MPa gauge pressure, 0.1-10 h-1, preferably 0.2-6 h-1, more preferably 0.4-2 h < -1 > (WHSV).

Typical process conditions in the steam cracking unit preferably include a pressure selected from a reaction temperature of approximately 750-900 占 폚, a residence time of 50-1000 milliseconds, and a pressure of 175 kPa gauge at atmospheric pressure.

A very common process for the conversion of alkanes to olefins involves "steam cracking ". As used herein, the term "steam cracking" refers to a petrochemical process in which saturated hydrocarbons are broken down into smaller, often unsaturated hydrocarbons, such as ethylene and propylene. In steam cracking, gaseous hydrocarbon feeds (gas cracking) such as ethane, propane and butane, or mixtures thereof, or liquid hydrocarbon feeds such as naphtha or gas oil (liquid cracking) are diluted with water vapor and simply And heated. Typically the reaction temperature is very high, approximately 850 DEG C, but the reaction takes place only very briefly, usually with a residence time of 50-500 milliseconds. Preferably, the hydrocarbon compounds ethane, propane and butane are decomposed separately in the specified furnace in order to be able to decompose under optimum conditions. After reaching the decomposition temperature, the gas is quenched quickly and the reaction is stopped in the transmission line heat exchanger or in the header header using the oil. Steam cracking results in a slow deposition of coke, carbon, in the reactor wall. Decoking requires a furnace isolated from the process, and then the flow of steam or a steam / air mixture passes through the coils of the furnace. This converts the hard solid carbon layer to carbon monoxide and carbon dioxide. Once this reaction is completed, the nose is returned for service. The products produced by steam cracking depend on the composition of the feed, the ratio of hydrocarbons to water vapor and the decomposition temperature and the residence time of the furnace. Light hydrocarbon feeds such as ethane, propane, butane or light naphtha provide a more rigid polymer grade olefin rich product stream, including ethylene, propylene and butadiene. Heavier hydrocarbons (full range and heavy naphtha and gas oil fractions) also provide products rich in aromatic hydrocarbons.

To separate the different hydrocarbon compounds produced by steam cracking, the cracked gas is applied to a fractionation unit. Such fractionation units are well known in the art and include so-called gasoline rectification towers in which heavy distillates ("carbon black oil") and intermediate distillates ("cracked distillate" ("pyrolysis gas" or "pygas") produced by steam cracking can be removed by condensing the hard-distillate The gas may be subjected to multiple compression stages and the remainder of the hard distillate may be separated from the gas during the compression stages and the acid gases (CO2 and H2S) In the next step, the gas produced by the pyrolysis can be partially removed on the stages of the cascade refrigeration system where only the hydrogen remains in the vapor phase. The different hydrocarbon compounds may then be separated by simple distillation and the ethylene, propylene and C4 olefins are the most important expensive chemicals produced by steam cracking. And the hydrogen may be separated and refluxed to a process that consumes hydrogen, such as a hydrocracking process. The acetylene produced by the steam cracking is preferably selectively hydrogenated with ethylene. The alkane may be refluxed into a process for converting an alkane to an olefin.

The term "propane dehydrogenation unit" as used herein relates to a petrochemical processing unit in which the propane feed stream is converted to a product comprising propylene and hydrogen. Thus, the term "butane dehydrogenation unit" relates to a process unit for converting a butane feed stream to C4 olefins. In addition, processes for dehydrogenating lower alkanes such as propane and butane are described as lower alkane dehydrogenation processes. Processes for lower alkane dehydrogenation are well known in the art and include a hydrogenation process and a non-oxidative dehydrogenation process. In an oxidative dehydrogenation process, the process heat is provided by partial oxidation of the alkane (s) lower than in the feed. In a non-oxidative dehydrogenation process, which is preferred in the context of the present invention, the process heat for the endothermic dehydrogenation reaction is provided by an external heat source, such as a hot flue gas obtained by burning fuel gas or water vapor . For example, the UOP Oleflex process can be carried out in the presence of a catalyst containing platinum supported on alumina in a mobile bed reactor to form de-hydrogenation of propane to form propylene and (iso) butylene (or mixtures thereof) Consider the dehydrogenation of (iso) butane for this purpose; See US 4,827,072. The Uhde STAR process considers the dehydrogenation of propane to form propylene and the dehydrogenation of butane to form butylene in the presence of a promoted platinum catalyst supported on a zinc-alumina spinel; See US 4,926,005. The STAR process has recently been improved by applying the principle of oxydehydrogenation. In the secondary adiabatic zone in the reactor, the portion of hydrogen from the intermediate product is converted with optionally added oxygen to form water. This shifts the thermodynamic equilibrium to higher conversions and yields higher yields. Further, the external heat required for the endothermic dehydrogenation reaction is partially supplied by the exothermic hydrogen conversion. The Lummus Catofin process employs a number of fixed bed reactors operating on a cyclical basis. The catalyst is activated alumina impregnated with 18-20 wt% chromium; See, for example, EP 0 192 059 A1 and GB 2 162 082 A. The Catofin process is reported to be able to handle impurities that are robust and poison platinum catalysts. The product produced by the butane dehydrogenation process depends on the nature of the butane feed and on the butane dehydrogenation process used. The Catofin process also considers the dehydrogenation of butane to form butylene; See, for example, US 7,622,623.

The hydrocarbon feedstock of step (a) may be selected from the group consisting of sail oil, crude oil, kerosene, diesel, atmospheric gas oil (AGO), gas condensate, wax, crude contaminated naphtha, Residues, atmospheric residues, naphtha and pretreated naphtha, or combinations thereof. Other preferred feedstocks are light cycle oil / heavy duty cycle oil (LCO / HCO), coker naphtha and diesel, FCC naphtha and diesel and even slurry oil.

Figure 1 is a schematic illustration of an embodiment of the process of the present invention.
Figure 2 is another embodiment of the process of the present invention.
Figure 3 is another embodiment of the process of the present invention.
Figure 4 is another embodiment of the process of the present invention.
Figure 5 is another embodiment of the process of the present invention.
Figure 6 is another embodiment of the process of the present invention.

BRIEF DESCRIPTION OF THE DRAWINGS The invention will be described in more detail below in connection with the appended drawings, wherein like or similar elements are represented by like numerals.

Referring now to the process and apparatus schematically depicted in FIG. 1, there is shown a process 101 for upgrading refinery heavy hydrocarbons to petrochemicals. The hydrocarbon feedstock 5 is sent to the loop open reaction zone 1 and its effluent 17 is fed to a gas stream 4 comprising LPG, a liquid stream 18 containing naphtha boiling range hydrocarbons, To a separation unit (2) that produces a liquid stream (15) comprising a range of hydrocarbons. The stream 15 comprising the diesel boiling range hydrocarbon is preferably refluxed to the inlet of the loop open reaction zone (1). The stream 18 containing the naphtha boiling range hydrocarbons is sent to the hydrocracking unit 3 which produces an overhead gas stream 9 comprising LPG and a bottoms stream 11 comprising aromatic hydrocarbons such as BTX . Stream 4 and stream 9 are combined as stream 10 and additionally in a dehydrogenation unit selected from the group of steam cracker unit and propane dehydrogenation unit, butane dehydrogenation unit and combined propane / butane dehydrogenation unit . In this embodiment, the gas stream 10 is first separated into separate streams 24, 25, 26 in the separation unit 20. However, the number of streams is not limited. The light hydrocarbon fraction 24 is sent to the gas steam cracker unit 22 and the effluent is sent to an additional separation zone 23 where the zone 23 may comprise several separation units. The streams 25 and 26 are treated in a dehydrogenation zone 21 which contains several dehydration units such as a propane dehydrogenation unit, a butane dehydrogenation unit and a combined propane / butane dehydrogenation unit And may include a hydrophobic unit. The dehydrogenated effluent 28 is sent to a separation unit 23 and is separated into individual streams 29, 30, streams containing, for example, olefins. However, the number of streams is not limited. According to another embodiment, the stream 4 is fed to a hydrocracking unit 3 (partially in the form of a condensate) which produces a bottoms gas stream 9 comprising LPG and a bottoms stream 11 comprising aromatic hydrocarbons such as BTX ).

According to step 201 (see FIG. 2), the hydrocarbon feedstock 5 is pre-treated in a splitter unit 5 which produces a stream 16 comprising hydrocarbons in the naphtha boiling range. The stream 16 is sent directly to the hydrocracking unit 3. The effluent of the splitter unit 5, which contains heavy hydrocarbons, is sent to the ring opening reaction zone 1. The loop-open reaction zone (1) produces an effluent stream (17). The stream 17 is sent to a separation unit 2 which produces a gas stream 4 comprising LPG, a stream 18 comprising naphtha boiling range hydrocarbons and a stream 15 comprising a diesel boiling range of hydrocarbons Loses. The stream 15 comprising the diesel boiling range hydrocarbon is preferably refluxed to the inlet of the loop open reaction zone (1). Stream 18 is further converted in the hydrocracking unit 3 to produce a bottoms gas stream 9 comprising LPG and a bottoms stream 11 comprising BTX. Stream 4 and stream 9 are combined as stream 10 and can be further processed as discussed in the discussion of FIG. According to another embodiment, the stream 4 is fed (partially) to a hydrocracking unit 3 which produces a bottoms gas stream 9 comprising LPG and a bottoms stream 11 comprising aromatic hydrocarbons such as BTX, Can be sent.

In addition to the splitter unit 5 as discussed above in Fig. 2, the yield towards BTX can be further improved by providing the hydro-decomposition unit 6. According to step 301 of FIG. 3, the hydrocarbon feedstock 5 is hydrolyzed and decomposed in a hydrolysis decomposition unit 6 to produce a bottoms stream 8 comprising a gas stream 13 and naphtha. The stream 8 is sent directly to the hydrocracking unit 3. The heavy fraction coming from the hydrolysis decomposition unit (6) is sent to the ring opening reaction zone (1). In the ring opening reaction zone 1, the hydrocarbons coming from the preheat hydrocracking unit 6 are converted to effluent 17. The effluent 17 comprises a separating unit 2 for producing a stream 15 comprising a gas stream 4 comprising LPG, a liquid stream 18 comprising naphtha boiling range hydrocarbons and a diesel boiling range hydrocarbon, Lt; / RTI > The stream 15 containing the diesel boiling range hydrocarbon is refluxed to the inlet of the hydrolysis decomposition unit 6. Stream 18 is fed to a hydrocracking unit 3 which produces a bottoms gas stream 9 comprising LPG and a bottoms stream 11 comprising BTX. Gas streams 4 and 9 are combined as stream 10 and stream 10 can be further processed as discussed above in FIG. According to another embodiment, the stream 4 and stream 13 comprise a hydrocracking unit 3 that produces a bottoms stream 11 comprising an overhead gas stream 9 comprising LPG and an aromatic hydrocarbon such as BTX, (Partially). In addition, the stream 13 can be sent (partially) to the loop open reaction zone 1.

3, the first hydrocracking step as discussed above in Fig. 3 may be replaced by a hydrogenated dealkylation unit 7, and the first hydrocracking step from unit 7 to BTXE < RTI ID = 0.0 > Stream 12 is obtained, and the gas stream 14 contains LPG. The heavier fraction coming from the unit 7 is sent to the loop open reaction zone 1 and produces an effluent 17. The effluent 17 from the loop open reaction zone 1 is fed to a stream 15 containing a gaseous stream 4 comprising LPG, a liquid stream 18 comprising a naphtha boiling range hydrocarbon and a diesel boiling range hydrocarbon (2). The stream 15 containing the diesel boiling range hydrocarbon is refluxed to the inlet of the hydrogenated dealkylation unit 7. Stream 18 is sent to a hydrocracking unit 3 which produces an overhead gas stream 9 containing LPG and a bottoms stream 11 comprising BTX. The BTXE-rich stream produced in the unit 7 can be further processed in the hydrocracking unit 3. Gas streams 14, 4 and 9 are combined as stream 10 and this stream can be further processed as discussed above in FIG. According to another embodiment (not shown), the stream 4 and the stream 14 are subjected to hydrogenation to produce a bottoms gas stream 9 comprising LPG and a bottoms stream 11 comprising aromatic hydrocarbons such as BTX (Partially) to the decomposition unit 3. In addition, the stream 14 can be sent (partially) to the loop open reaction zone 1.

In a preferred embodiment, as shown in FIG. 5, according to a process 501 for upgrading refined heavy hydrocarbons to petrochemicals, the hydrocarbon feedstock 5 is sent to the ring opening reaction zone 1, The water 17 comprises a separation unit 2 for producing a liquid stream 15 comprising a gaseous stream 4 comprising LPG, a liquid stream 18 comprising naphtha boiling range hydrocarbons and a diesel boiling range hydrocarbon, Lt; / RTI > The stream 15 containing the diesel boiling range hydrocarbon can be refluxed (partially) to the inlet of the ring opening reaction zone 1. 5 also shows that a stream 15 containing the diesel boiling range hydrocarbon is sent to the aromatic saturation unit 50 which produces stream 51 as stream 49. The remaining process units and streams are similar to those mentioned above in Fig. According to another embodiment, the stream 4 is sent (partially) to a hydrocracking unit 3 which produces a bottoms gas stream 9 comprising LPG and a bottoms stream 11 comprising aromatic hydrocarbons such as BTX It can be done.

According to another preferred embodiment, at least a portion of benzene and toluene, and a carbon aromatic compound of 9 and 10, are introduced into the transalkylation zone. According to this embodiment, stream 11 is introduced into transalkylation zone 60 to increase the production of xylene compounds produced in stream 62, as shown in FIG. 6 as process 601. A once through hydrogen rich gas stream 61 is also introduced into the transalkylation zone 60. This gas stream 61 may be obtained from other hydrogen generating units, such as hydrogen recovered from the reaction products of the steam cracking unit and the dehydrogenation unit. The operating conditions preferably employed in the transalkylation zone include a temperature of 177 캜 to 525 캜 and a liquid hourly space velocity of from 0.2 to 10 hours. Any suitable transalkylation catalyst may be used in the transalkylation zone. Preferred transalkylation catalysts contain molecular sieves, refractory inorganic oxides, and reduced reduced-framework weak metals. Preferred molecular sieves are zeolite aluminosilicates, such as zeolites in the MFI form, which may be any of those having a silica ratio to alumina of greater than 10 and pore diameters of 5 to 8 angstroms. According to another embodiment, the stream 4 is fed (partially) to a hydrocracking unit 3 which produces a bottoms gas stream 9 comprising LPG and a bottoms stream 11 comprising aromatic hydrocarbons such as BTX, Can be sent.

Example

The process scheme used herein corresponds to that shown in FIG. The hydrocarbon feedstock 5 is fed to the reaction zone 1 for ring opening and the reaction product 17 produced from the reaction zone is fed by the unit 2 to the top stream 4, 18 and a bottoms stream 15. The site stream 18 is fed to a gasoline hydrocracker (GHC) unit 3 and the reaction product of the GHC unit 3 is fed to an overhead gas stream 9 comprising a light component such as C2-C4 paraffin, hydrogen and methane ) And a stream (11) mainly comprising an aromatic hydrocarbon ring and a non-aromatic hydrocarbon compound. The overhead gas stream 9 from the gasoline hydrocracker unit (GHC) 3 is combined with the stream 4 from the unit 2.

In case 1 (embodiment according to the invention), kerosene as feedstock is sent to the reaction zone for ring opening, these side streams are sent to a gasoline hydrocracker (GHC) unit, the LPG fraction is fed to unit 2 ). ≪ / RTI >

According to Case 2 (embodiment according to the invention), hard vacuum gas oil (LVGO) as feedstock is sent to the reaction zone for ring opening, these side streams are sent to a gasoline hydrocracker (GHC) unit, The LPG fraction is separated from the top of the unit (2).

The characteristics of kerosene and LVGO are shown in Table 1. Table 2 shows the distribution of aromatic molecules (Di + aromatic) with monoaromatic and more than one ring in the feed. Table 3 shows the battery limit product slate (wt.% Of feedstock).

Table 1: Characteristics of kerosene and LVGO

                              Kerosene LVGO

n-paraffin wt .-% 23.7 18.3

i-Paraffin wt .-% 17.9 13.8

Naphthene wt .-% 37.4 35.8

Aromatic wt .-% 21.0 32.0

Density 60F Kg / L 0.810 0.913

IBP ° C 174 306

BP10 ℃ 196 345

BP30 ℃ 206 367

BP 50 ° C 216 384

BP 70 ° C 226 404

BP 90 ° C 242 441

FBP ℃ 266 493

Table 2: Classification of aromatic molecules as a function of number of aromatic rings in kerosene and LVGO

                               Kerosene LVGO

Wt.% Of total aromatic feed 21.0% 32.0

Wt .-% 12.5 9.0 of mono-aromatic feed

Die + wt% of aromatic feed 8.5% 23.0

Table 3: Battery Limit Product Slate (wt.% Of feedstock)

Ingredient Case 1: Kerosene Case 2: LVGO

LPG 87.8 89.4

Ethane 24.8 25.3

Propane 54.1 55.1

n-butane 7.1 7.2

Iso-butane 1.8 1.8

BTX 12.2 10.6

Benzene 3.3 2.9

Toluene 5.9 5.1

Xylene 3.0 2.6

The data presented above show that the reaction zone for the ring opening of the feed and the presence of gasoline hydrocracking (GHC) convert multi-ring aromatic molecules into more valuable single-ring aromatics and LPG. In addition, BTX is also obtained from the dehydrogenation of naphthenic mono-ring aromatics.

Claims (15)

Process for upgrading purified heavy hydrocarbons to petrochemicals, comprising the steps of:
(a) feeding a hydrocarbon feedstock to an open loop reaction zone;
(b) feeding the effluent from (a) into a separation unit to produce a liquid stream comprising a gaseous stream comprising low boiling hydrocarbons, a liquid stream comprising hydrocarbons in the naphtha boiling range, and hydrocarbons in the diesel boiling range, ;
(c) feeding the liquid stream comprising hydrocarbons in the naphtha boiling range to a hydrocracking unit;
(d) separating the reaction product of the hydrocracking unit of step (c) into a bottoms stream comprising a top gas stream comprising low boiling hydrocarbons and a BTX (mixture of benzene, toluene and xylene)
(e) separating the overhead gas stream from the hydrocracking unit of step (d) and the gaseous stream from the separate unit of step (b), preferably after separating the hydrogen-containing stream from the gas stream, Propane dehydrogenation unit, butane dehydrogenation unit, and coupled propane-butane dehydrogenation unit. The method according to claim 1,
Supplying an overhead gas stream from the hydrocracking unit of step (d) and a gaseous stream from the separate unit of step (b) to another separation unit and thereby to separate the separated stream from the steam cracking unit and the dehydrogenation unit ). ≪ / RTI > 3. The method according to claim 1 or 2,
The dehydrogenation process is a contacting process, and the steam cracking process is a pyrolysis process. 4. The method according to any one of claims 1 to 3,
Further comprising the step of pretreating said hydrocarbon feedstock in an aromatic extraction unit from which the aromatic rich stream is fed to the reaction zone for said ring opening and in particular said aromatic extraction unit is fed in the form of a distillation unit , Molecular sieve form and solvent extraction unit, and in particular
Further comprising the step of pre-treating the hydrocarbon feedstock in a splitter unit, wherein a hydrocarbon fraction ranging from naphtha boiling from the splitter unit is fed directly to the hydrocracking unit, Is supplied to the open reaction region, and particularly
Further comprising pretreating said hydrocarbon feedstock in a pre-hydrocracking unit, wherein the heavier hydrocarbon fraction from the total hydrocracking unit is fed to said ring opening reaction zone and said hydrocarbon feedstock comprises a naphtha boiling range hydrocarbon The stream is fed directly to the hydrocracking unit and the gaseous stream comprising LPG is passed to the hydrocracking unit and to at least one unit selected from the group of a propane dehydrogenating unit, a butane dehydrogenating unit and a combined propane-butane dehydrogenating unit And particularly
Further comprising the step of pretreating said hydrocarbon feedstock in a hydrogenated dealkylation / reforming type unit, wherein a BTXE form stream is obtained from the hydrogenated dealkylation / reformate type unit, a heavy hydrocarbon fraction is fed to said ring opening reaction zone, Wherein the gas stream comprising LPG is fed to at least one unit selected from the group consisting of a steam cracking unit and a propane dehydrogenating unit, a butane dehydrogenating unit and a combined propane-butane dehydrogenating unit. 5. The method according to any one of claims 1 to 4,
Supplying at least one of the gas stream from the separation unit of step (b), the gas stream from the hydrodeoxyalkylation / reformate unit and the gas stream from the hydrolysis decomposition unit to the hydrocracking unit ≪ / RTI > 6. The method according to any one of claims 2 to 5,
Further comprising feeding the bottoms stream from the hydrocracking unit to a transalkylation unit. 7. The method according to any one of claims 1 to 6,
Further comprising the step of feeding said liquid stream comprising a hydrocarbon boiling range hydrocarbon from said separation unit to an aromatic saturation unit. 8. The method according to any one of claims 1 to 7,
Separating the overhead stream from the hydrocracking unit, the gaseous stream from the separation unit in step (b), and possibly the gaseous stream from the hydrocracking unit and the hydrodealkylation / reformate unit, into individual streams Wherein each stream primarily comprises C2 paraffin, C3 paraffin, and C4 paraffin, and supplies each individual stream to a specific furnace region of the steam cracker unit, wherein the hydrogen containing stream is fed to one or more hydrogen- For example, to the (hydro) cracking unit and the reaction zone for the ring opening,
Feeding only the C3-C4 fraction to at least one of the dehydrogenation units, particularly as separate C3 and C4 streams, more preferably as a combined C3 + C4 stream. 9. The method according to any one of claims 1 to 8,
The prevailing process conditions in the reaction zone for the ring opening are a temperature of 100 ° C to 500 ° C and a pressure of 2 to 10 MPa with 50 to 300 kg of hydrogen per 1000 kg of feedstock on the aromatic hydrogenation catalyst, To the ring-breaking unit at a temperature of 200 ° C to 600 ° C and a pressure of 1 to 12 MPa, with 50 kg to 200 kg of hydrogen per 1000 kg of the resulting stream on the ring-cut catalyst. 10. The method according to any one of claims 1 to 9,
Typical process conditions in the separation unit are a temperature of 149 DEG C to 288 DEG C and a pressure of 1 MPa to 17.3 MPa. 11. The method according to any one of claims 1 to 10,
Typical process conditions in the hydrocracking unit are a reaction temperature of 300-580 ° C, preferably 450-580 ° C, more preferably 470-550 ° C, a pressure of 0.3-5 MPa gauge pressure, preferably a pressure of 0.6-3 MPa gauge Particularly preferably from 1000 to 2000 kPa gauge pressure, most preferably from 1 to 2 MPa gauge pressure, most preferably from 1.2 to 1.6 MPa gauge pressure, from 0.1 to 10 h-1, preferably from 0.2 to 6 h- 1, more preferably 0.4-2 h < -1 > (WHSV). 12. The method according to any one of claims 1 to 11,
Typical process conditions in the steam cracking unit are a reaction temperature of approximately 750-900 ° C, a residence time of 50-1000 milliseconds and a pressure selected from below 175 kPa gauge at atmospheric pressure. 13. The method according to any one of claims 1 to 12,
The hydrocarbon feedstock of step (a) may be selected from the group consisting of sail oil, crude oil, kerosene, diesel, atmospheric gas oil (AGO), gas condensate, wax, crude contaminated naphtha, Processes which are residues, atmospheric residues, naphtha and pretreated naphtha, light recirculating oil / heavy recirculating oil (LCO / HCO), coker naphtha and diesel, FCC naphtha and diesel and slurry oils, or combinations thereof. Use as feedstock for aromatic saturated units, multi-stage loop open hydrocracked hydrocarbons feedstock diesel boiling range hydrocarbons. The use of a high boiling range hydrocarbon fraction of a multi-stage loop open hydrocracked hydrocarbon feedstock as feedstock for a transalkylation unit.

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