CN114423845A - Multiple dense phase risers for maximizing aromatic hydrocarbon yield from naphtha catalytic cracking - Google Patents
Multiple dense phase risers for maximizing aromatic hydrocarbon yield from naphtha catalytic cracking Download PDFInfo
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- 150000004945 aromatic hydrocarbons Chemical class 0.000 title claims description 32
- 238000004523 catalytic cracking Methods 0.000 title abstract description 13
- 239000003054 catalyst Substances 0.000 claims abstract description 122
- 238000000034 method Methods 0.000 claims abstract description 86
- 239000002245 particle Substances 0.000 claims abstract description 56
- 150000001336 alkenes Chemical class 0.000 claims abstract description 36
- 239000007787 solid Substances 0.000 claims abstract description 26
- 229930195733 hydrocarbon Natural products 0.000 claims abstract description 20
- 150000002430 hydrocarbons Chemical class 0.000 claims abstract description 20
- 239000007789 gas Substances 0.000 claims description 58
- 230000008569 process Effects 0.000 claims description 50
- 238000006243 chemical reaction Methods 0.000 claims description 44
- 239000000047 product Substances 0.000 claims description 30
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 claims description 16
- 238000004891 communication Methods 0.000 claims description 15
- 239000012530 fluid Substances 0.000 claims description 15
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims description 14
- 239000003546 flue gas Substances 0.000 claims description 13
- UGFAIRIUMAVXCW-UHFFFAOYSA-N Carbon monoxide Chemical compound [O+]#[C-] UGFAIRIUMAVXCW-UHFFFAOYSA-N 0.000 claims description 12
- 239000000203 mixture Substances 0.000 claims description 12
- JTJMJGYZQZDUJJ-UHFFFAOYSA-N phencyclidine Chemical class C1CCCCN1C1(C=2C=CC=CC=2)CCCCC1 JTJMJGYZQZDUJJ-UHFFFAOYSA-N 0.000 claims description 10
- 230000008929 regeneration Effects 0.000 claims description 10
- 238000011069 regeneration method Methods 0.000 claims description 10
- 239000004215 Carbon black (E152) Substances 0.000 claims description 7
- 229910052757 nitrogen Inorganic materials 0.000 claims description 7
- 239000006227 byproduct Substances 0.000 claims description 5
- JRZJOMJEPLMPRA-UHFFFAOYSA-N olefin Natural products CCCCCCCC=C JRZJOMJEPLMPRA-UHFFFAOYSA-N 0.000 claims description 5
- 239000011261 inert gas Substances 0.000 claims description 4
- 239000000463 material Substances 0.000 claims description 4
- 239000003795 chemical substances by application Substances 0.000 claims description 2
- 238000002156 mixing Methods 0.000 abstract description 4
- UHOVQNZJYSORNB-UHFFFAOYSA-N Benzene Chemical compound C1=CC=CC=C1 UHOVQNZJYSORNB-UHFFFAOYSA-N 0.000 description 12
- YXFVVABEGXRONW-UHFFFAOYSA-N Toluene Chemical compound CC1=CC=CC=C1 YXFVVABEGXRONW-UHFFFAOYSA-N 0.000 description 12
- 238000004519 manufacturing process Methods 0.000 description 12
- 239000010457 zeolite Substances 0.000 description 7
- 229910021536 Zeolite Inorganic materials 0.000 description 6
- HNPSIPDUKPIQMN-UHFFFAOYSA-N dioxosilane;oxo(oxoalumanyloxy)alumane Chemical compound O=[Si]=O.O=[Al]O[Al]=O HNPSIPDUKPIQMN-UHFFFAOYSA-N 0.000 description 6
- 238000005336 cracking Methods 0.000 description 5
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- 238000010586 diagram Methods 0.000 description 3
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- -1 BTX Chemical class 0.000 description 2
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- 230000003197 catalytic effect Effects 0.000 description 2
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- 238000005984 hydrogenation reaction Methods 0.000 description 2
- 239000002994 raw material Substances 0.000 description 2
- 238000012546 transfer Methods 0.000 description 2
- 229910000975 Carbon steel Inorganic materials 0.000 description 1
- LGRFSURHDFAFJT-UHFFFAOYSA-N Phthalic anhydride Natural products C1=CC=C2C(=O)OC(=O)C2=C1 LGRFSURHDFAFJT-UHFFFAOYSA-N 0.000 description 1
- 239000004793 Polystyrene Substances 0.000 description 1
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- 238000013459 approach Methods 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000009835 boiling Methods 0.000 description 1
- JHIWVOJDXOSYLW-UHFFFAOYSA-N butyl 2,2-difluorocyclopropane-1-carboxylate Chemical compound CCCCOC(=O)C1CC1(F)F JHIWVOJDXOSYLW-UHFFFAOYSA-N 0.000 description 1
- 229910052799 carbon Inorganic materials 0.000 description 1
- 239000010962 carbon steel Substances 0.000 description 1
- 238000001833 catalytic reforming Methods 0.000 description 1
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- 229920001778 nylon Polymers 0.000 description 1
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- 238000011020 pilot scale process Methods 0.000 description 1
- 239000004033 plastic Substances 0.000 description 1
- 229920003023 plastic Polymers 0.000 description 1
- 229920000515 polycarbonate Polymers 0.000 description 1
- 239000004417 polycarbonate Substances 0.000 description 1
- 229920000728 polyester Polymers 0.000 description 1
- 229920000642 polymer Polymers 0.000 description 1
- 229920002223 polystyrene Polymers 0.000 description 1
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- 150000003738 xylenes Chemical class 0.000 description 1
Images
Classifications
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- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G11/00—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils
- C10G11/14—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts
- C10G11/18—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts according to the "fluidised-bed" technique
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G11/00—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils
- C10G11/14—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts
- C10G11/18—Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts according to the "fluidised-bed" technique
- C10G11/187—Controlling or regulating
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
- C10G2300/10—Feedstock materials
- C10G2300/1037—Hydrocarbon fractions
- C10G2300/1044—Heavy gasoline or naphtha having a boiling range of about 100 - 180 °C
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
- C10G2300/40—Characteristics of the process deviating from typical ways of processing
- C10G2300/4018—Spatial velocity, e.g. LHSV, WHSV
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
- C10G2300/70—Catalyst aspects
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G2400/00—Products obtained by processes covered by groups C10G9/00 - C10G69/14
- C10G2400/20—C2-C4 olefins
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G2400/00—Products obtained by processes covered by groups C10G9/00 - C10G69/14
- C10G2400/30—Aromatics
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- Chemical & Material Sciences (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Engineering & Computer Science (AREA)
- Chemical Kinetics & Catalysis (AREA)
- General Chemical & Material Sciences (AREA)
- Organic Chemistry (AREA)
- Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
- Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)
Abstract
Systems and methods for producing aromatics and olefins by catalytic cracking are disclosed. The naphtha feed stream and the lift gas stream are fed to one or more dense phase riser reactors, each operating at a high volume fraction of solids, high superficial velocity, high back mixing. The effluent streams from all dense phase riser reactors are further separated in a secondary reactor into a gaseous product stream and a catalyst stream. The catalyst stream is stripped to remove hydrocarbons adsorbed on the catalyst particles. The stripped catalyst is regenerated in a regenerator.
Description
Cross Reference to Related Applications
This application claims priority to U.S. provisional patent application No. 62/883069 filed on 5.8.2019, which is incorporated herein by reference in its entirety.
Technical Field
The present invention relates generally to systems and methods for producing aromatics and olefins. More particularly, the present invention relates to a system and process for producing aromatic hydrocarbons and olefins by catalytically cracking naphtha in a dense phase riser reactor.
Background
BTX (benzene, toluene and xylene) is a group of aromatic hydrocarbons used in many different fields of the chemical industry, in particular in the plastics and polymer fields. For example, benzene is a precursor for the preparation of polystyrene, phenolic resins, polycarbonates, and nylons. Toluene is used for the preparation of polyurethanes and as a gasoline component. Xylene is a feedstock for the production of polyester fibers and phthalic anhydride. In the petrochemical industry, benzene, toluene and xylenes are typically produced by catalytic reforming of naphtha.
The demand for aromatic hydrocarbons, particularly BTX, has continued to increase over the past few decades. One of the conventional processes for producing BTX involves steam cracking of a hydrocarbon feedstock such as naphtha. However, the overall efficiency of this conventional approach is relatively low. In addition to the aromatic hydrocarbons, other products are produced including olefins, which compete with the aromatic hydrocarbons in the process. In addition, a significant amount of the hydrocarbons in the effluent are recovered to the steam cracker. Since the hydrocarbons must be hydrotreated before being recycled to the steam cracker, the large amount of hydrocarbons to be recycled requires a large amount of hydrogen and energy in the hydrogenation process, resulting in high production costs.
Another conventional process for producing aromatic hydrocarbons (e.g., BTX) involves catalytically cracking naphtha in a fluidized bed. However, these conventional fluidized bed reactors typically operate with low average volume fraction of solids and low gas-solid contact efficiency due to the limitation of superficial gas velocity in the fluidized bed. Thus, the products of conventional processes often contain high methane content resulting from the thermal cracking of hydrocarbons, resulting in increased production costs of aromatic hydrocarbons.
In summary, despite the existence of processes for the production of lower olefins, there is still a need for improvements in this field, at least in view of the above-mentioned disadvantages of these processes.
Disclosure of Invention
Solutions to at least some of the above-mentioned problems associated with aromatic (e.g., BTX) production processes that use naphtha as a feedstock have been discovered. The solution is a process for producing aromatics and olefins comprising catalytically cracking naphtha using one or more dense phase riser reactors. The superficial gas velocity in the one or more dense phase riser reactors is significantly higher than in conventional processes. This is beneficial to provide a high volume fraction of solids at least in each riser reactor, thereby reducing the occurrence of thermal cracking of naphtha. In addition, the lift gas used in the dense phase riser reactor is free of steam. Thus, zeolite-based catalysts can be used and are not subject to steam dealumination, with zeolite-based catalysts having higher efficiencies than non-zeolite-based catalysts. In addition, the process allows for sufficient back mixing in the dense phase riser reactor characterized by a wide Residence Time Distribution (RTD) with a relative variance greater than 0.33, thereby increasing the ratio of BTX to olefins in the dense phase riser reactor effluent. Accordingly, the process of the present invention provides a solution to at least some of the problems associated with the above-described prior art processes for producing aromatic hydrocarbons.
Embodiments of the invention include methods of making aromatic hydrocarbons and/or olefins. The process comprises contacting naphtha with catalyst particles in a dense phase riser reactor having an average volume solids fraction of at least 0.08 at reaction conditions sufficient to produce a first product comprising one or more than one olefin and/or one or more than one aromatic hydrocarbon. The dense phase riser reactor is operated at a superficial gas velocity of from 4m/s to 20 m/s. The process also includes passing a mixture of the first product, catalyst particles, and unreacted naphtha to a cyclone system disposed in the secondary reactor. The secondary reactor is stacked on top of the regenerator. The method also includes separating the first product from the catalyst particles in a cyclone system. The method also includes stripping hydrocarbon vapors from the catalyst particles in a stripper disposed in the regenerator to produce stripped catalyst particles. The method also includes regenerating the stripped catalyst particles in a regenerator.
Embodiments of the invention include methods of making aromatic hydrocarbons and/or olefins. The process comprises contacting naphtha with catalyst particles in a dense phase riser reactor under reaction conditions sufficient to produce a first product comprising one or more than one aromatic hydrocarbon and/or one or more than one olefin. The dense phase riser reactor is operated at a superficial gas velocity of from 4m/s to 20 m/s. The dense phase riser reactor has an internal diameter of 2.0 to 2.75 m. The volume fraction of Solids (SVF) in the dense phase riser reactor is from 0.1 to 0.2. The process also includes passing a mixture of the first product, catalyst particles, and unreacted naphtha to a cyclone system disposed in the secondary reactor. The secondary reactor is stacked on top of the regenerator. The method also includes separating the first product from the catalyst particles in a cyclone system. The method also includes stripping hydrocarbon vapors from the catalyst particles in a stripper disposed in the regenerator to produce stripped catalyst particles. The method also includes regenerating the stripped catalyst particles in a regenerator.
Embodiments of the invention include a reaction unit for producing olefins and/or aromatics. The reaction apparatus comprises one or more dense phase riser reactors. Each dense phase riser reactor comprises a shell, a feed inlet disposed on a lower half of the shell adapted to receive feed into the shell, a lift gas inlet disposed on the lower half of the shell adapted to receive lift gas into the shell, a catalyst inlet disposed on the lower half of the shell adapted to receive catalyst into the shell, and an outlet disposed on an upper half of the shell adapted to release effluent from the dense phase riser from the shell. The reaction apparatus further comprises a secondary reactor in fluid communication with the outlet of each dense phase riser reactor. The secondary reactor includes one or more cyclones adapted to separate the effluent of the dense phase riser into a gaseous stream comprising gaseous products and a solids stream comprising catalyst. The reaction apparatus also includes a regenerator in fluid communication with the secondary reactor adapted to receive the solids stream from the secondary reactor and regenerate the catalyst of the solids stream. The regenerator is in fluid communication with the catalyst inlet of each dense phase riser reactor.
The following includes definitions of various terms and phrases used throughout this specification.
The term "about" or "approximately" is defined as being approximately as understood by one of ordinary skill in the art. In one non-limiting embodiment, these terms are defined as a deviation within 10%, preferably within 5%, more preferably within 1%, and most preferably within 0.5%.
The terms "weight%", "volume%" or "mole%" refer to the weight percent, volume percent, or mole percent of a component, respectively, based on the total weight, volume, or total moles of the material comprising the component. In one non-limiting example, 10 mole of a component in 100 moles of material is 10 mole% of the component.
The term "substantially" and variations thereof are defined to include ranges within 10%, within 5%, within 1%, or within 0.5%.
The terms "inhibit" or "reduce" or "prevent" or "avoid" when used in the claims and/or the specification includes any measurable decrease or complete inhibition that achieves the desired result.
The term "effective" as used in the specification and/or claims means sufficient to achieve a desired, expected, or expected result.
When used in conjunction with the terms "comprising," including, "" containing, "or" having "in the claims or specification, preceding an element by a non-quantitative term may mean" one, "but also consistent with the meaning of" one or more, "" at least one, "and" one or more than one.
The words "comprising," "having," "including," or "containing" are inclusive or open-ended and do not exclude additional, unrecited elements or method steps.
The methods of the present invention can "comprise," "consist essentially of," or "consist of" the particular ingredients, components, compositions, etc. disclosed throughout the specification.
The term "predominantly" as used in the specification and/or claims refers to any one of greater than 50% by weight, 50% by mole, and 50% by volume. For example, "predominantly" can include 50.1% to 100% by weight and all values and ranges therebetween, 50.1% to 100% by mole and all values and ranges therebetween, or 50.1% to 100% by volume and all values and ranges therebetween.
Other objects, features and advantages of the present invention will become apparent from the drawings, detailed description and examples which follow. It should be understood, however, that the drawings, detailed description and examples, while indicating specific embodiments of the present invention, are given by way of illustration only and are not intended to be limiting. It is further contemplated that changes and modifications within the spirit and scope of the invention will become apparent to those skilled in the art from this detailed description. In other embodiments, features from specific embodiments may be combined with features from other embodiments. For example, features from one embodiment may be combined with features from any of the other embodiments. In other embodiments, additional features may be added to the specific embodiments described herein.
Drawings
For a more complete understanding, reference is now made to the following descriptions taken in conjunction with the accompanying drawing, in which:
FIG. 1 shows a schematic diagram of a reaction apparatus for producing aromatic hydrocarbons and/or olefins according to an embodiment of the present invention; and
fig. 2 shows a schematic flow diagram of a method for producing aromatic hydrocarbons and/or olefins according to an embodiment of the present invention.
Detailed Description
Currently, aromatic hydrocarbons, particularly BTX and lower olefins, can be produced by steam cracking or catalytic cracking of naphtha. However, the overall conversion of steam cracked naphtha to BTX and/or lower olefins is low. In addition, steam cracked naphtha is costly to produce because it produces a large amount of raffinate that needs to be hydrotreated before being recycled to the steam cracker. Thus, the large amount of raffinate results in high hydrogen and energy requirements in the hydrogenation process. Conventional naphtha catalytic cracking processes typically have low superficial gas velocities and extremely high catalyst-to-oil ratios in the catalyst bed, which leads to the challenge of maintaining pressure balance in the reactor. In addition, conventional naphtha catalytic cracking uses steam as the lift gas, which prevents the use of zeolite-based catalysts with high catalytic efficiency for BTX and lower olefins. The present invention provides a solution to at least some of these problems. The solution is premised on a process for catalytically cracking naphtha in a reaction unit comprising one or more dense phase riser reactors. The process is capable of maintaining a high volume fraction of solids and a high superficial gas velocity in the dense phase riser reactor, thereby reducing thermal cracking of naphtha and increasing the yield of BTX and/or lower olefins. In addition, the process includes substantial backmixing of the catalyst and hydrocarbons in the dense phase riser reactor. Thus, selectivity to aromatic hydrocarbons (e.g., BTX) is increased as compared to conventional processes. In addition, the process uses a steam-free lift gas, so that a zeolite-based catalyst can be used in the reaction apparatus, thereby improving the production efficiency of BTX and lower olefins. These and other non-limiting aspects of the invention are discussed in further detail in the following sections.
A. System for catalytic cracking of naphtha to produce aromatics and olefins
In an embodiment of the present invention, a reactor apparatus for producing aromatic hydrocarbons and olefins by catalytic cracking of naphtha comprises one or more dense phase riser reactors, a secondary reactor for gas-solid separation, and a regenerator. Referring to FIG. 1, a schematic diagram of a reaction apparatus 100 is shown, the reaction apparatus 100 being configured to produce aromatic hydrocarbons (e.g., BTX) and/or olefins (e.g., C)2And C3Olefins) and has improved BTX production efficiency and yield compared to conventional steam cracking or catalytic cracking processes. According to an embodiment of the present invention, the reaction apparatus 100 may comprise one or more dense phase riser reactors 101 comprising a shell 102, a feed inlet 103, a lift gas inlet 104, a catalyst inlet 105, and an effluent outlet 106. In an embodiment of the invention, the dense phase riser reactionVessel 101 is a fluidized bed reactor.
In an embodiment of the present invention, the housing 102 is made of carbon steel, refractory material, or a combination thereof. The shell 102 is adapted for catalytic cracking of naphtha. According to an embodiment of the present invention, the feed inlet 103 may be disposed in the lower half of the housing 102 and adapted to receive a feed stream therein. In an embodiment of the invention, the feed stream comprises naphtha. In an embodiment of the present invention, a lift gas inlet 104 is disposed in a lower half of the housing 102 and is adapted to receive lift gas in the housing 102. In an embodiment of the invention, the lift gas inlet 104 may be disposed below the feed inlet 103. The lift gas stream may include nitrogen, methane, any inert gas, or combinations thereof. In an embodiment of the present invention, the catalyst inlet 105 is disposed in the lower half of the housing 102. The catalyst inlet 105 may be adapted to receive catalyst particles into the housing 102. Non-limiting examples of catalyst particles may include zeolites. According to embodiments of the invention, the catalyst particles have a particle size of 75 μm to 120 μm and all ranges and values therebetween, including 75 μm to 78 μm, 78 μm to 81 μm, 81 μm to 84 μm, 84 μm to 87 μm, 87 μm to 90 μm, 90 μm to 93 μm, 93 μm to 96 μm, 96 μm to 99 μm, 99 μm to 102 μm, 102 μm to 105 μm, 105 μm to 108 μm, 108 μm to 111 μm, 111 μm to 114 μm, 114 μm to 117 μm, and 117 μm to 120 μm. The catalyst particles had a particle size of 1000kg/m3To 1700kg/m3And density of all ranges and values therebetween, including 1000kg/m3To 1100kg/m3、1100kg/m3To 1200kg/m3、1200kg/m3To 1300kg/m3、1300kg/m3To 1400kg/m3、1400kg/m3To 1500kg/m3、1500kg/m3To 1600kg/m3、1600kg/m3To 1700kg/m3. In embodiments of the invention, the catalyst inlet 105 may be disposed above the lift gas inlet 104. According to an embodiment of the invention, the lift gas inlet 104 is arranged below the feed inlet 103 and the catalyst inlet 105.
In embodiments of the present invention, each dense phase riser reactor 101 can be substantially cylindrical. The dense phase riser reactor 101 can have a height to diameter ratio of 8 to 27 and all ranges and values therebetween, including 8 to 9, 9 to 11, 11 to 13, 13 to 15, 15 to 17, 17 to 19, 19 to 21, 21 to 23, 23 to 25, and 25 to 27. In embodiments of the present invention, each dense phase riser reactor 101 has an inner diameter in the range of from 2.0m to 2.75m and ranges and values therebetween. According to an embodiment of the present invention, each dense phase riser reactor 101 includes an outlet 106 in fluid communication with a secondary reactor 107 such that the effluent of the dense phase riser reactor 101 flows from the dense phase riser reactor 101 to the secondary reactor 107.
The effluent from the dense phase riser reactor 101 may include unreacted naphtha, aromatics, lower olefins, lift gas, spent catalyst particles, and any other by-products. According to an embodiment of the present invention, secondary reactor 107 is adapted to separate the effluent from dense phase riser reactor 101 into a product gas stream and a spent catalyst stream. The product gas stream may include unreacted naphtha, aromatics, lower olefins, lift gas, by-products, or combinations thereof. The spent catalyst stream may include spent catalyst particles, hydrocarbons adsorbed on the spent catalyst particles, lift gas, or a combination thereof.
According to an embodiment of the present invention, the secondary reactor 107 comprises a secondary reactor shell 108 and one or more cyclones 109 adapted to separate the effluent from the riser reactor 108 into spent catalyst particles and a product gas. In an embodiment of the invention, each cyclone 109 in the secondary reactor 107 is a single stage cyclone or a multi-stage cyclone. Each cyclone 109 may be in fluid communication with a dipleg. The diplegs are adapted to transfer catalyst particles from the cyclones to the dense bed near the bottom of the secondary reactor 107. In an embodiment of the invention, the dipleg of each cyclone 109 is also in fluid communication with a splash plate and/or trickle valve. The splash plate and/or trickle valve may be adapted to avoid gas bypassing the dipleg of the cyclone.
In an embodiment of the present invention, the bottom end of secondary reactor 107 may be in fluid communication with regenerator 110 such that the spent catalyst stream flows from secondary reactor 107 to catalyst regenerator 110. In an embodiment of the present invention, the regenerator 110 is adapted to strip hydrocarbons adsorbed on spent catalyst and regenerate spent catalyst after the stripping process. The regenerator 110 is also adapted to separate the flue gas from the catalyst. According to an embodiment of the present invention, secondary reactor 107 is stacked on top of regenerator 110 such that spent catalyst particles may flow directly from secondary reactor 107 to regenerator 110 without any additional driving force other than gravity.
According to an embodiment of the present invention, regenerator 110 includes a stripper 111 configured to strip hydrocarbons adsorbed on spent catalyst particles. Stripping column 111 may include a stripping gas distributor 112 configured to release a stripping gas to contact the spent catalyst. Non-limiting examples of stripping gases may include nitrogen, methane, flue gases, and combinations thereof. The stripper column 111 can further include a stripper column internals 113 configured to enhance countercurrent contact between the downwardly flowing emulsion phase stream and the upwardly flowing bubble stream in the fluidized bed stripper column. Stripper internals 113 may include disc-like structural internals, chevron structural internals, packed internals, metro grid internals, or combinations thereof. Stripper column internals 113 can also include a standpipe 114 adapted to transfer catalyst particles from stripper column 111 to regenerator 110 and a slide valve adapted to control the flow rate of catalyst particles from stripper column 111 to regenerator 110. In an embodiment of the present invention, the catalyst regenerator 110 further comprises an air inlet 115 in fluid communication with an air distributor 116 disposed in the catalyst regeneration device 112 such that air is supplied to the regenerator 110 through the air inlet 115 and the air distributor 116. According to an embodiment of the present invention, the catalyst regenerator 110 further comprises one or more cyclones (e.g., cyclone 18) adapted to separate flue gas from catalyst. The flue gas may include flue gas generated during catalyst regeneration. According to an embodiment of the present invention, the catalyst regenerator 110 comprises one or more catalyst outlets 117, each catalyst outlet 117 being in fluid communication with the catalyst inlet 105 of each dense phase riser reactor 101 such that regenerated catalyst flows from the catalyst regenerator 110 to each dense phase riser reactor 110. In an embodiment of the present invention, secondary reactor 107, stripping column 111 and regenerator 110 are operated with a plurality of dense phase riser reactors 101.
B. Process for producing aromatic hydrocarbons and olefins
A process has been discovered for producing aromatics and olefins by catalytically cracking naphtha. Embodiments of the process can increase the volume fraction of solids in the reaction unit and minimize the occurrence of thermal cracking of hydrocarbons as compared to conventional catalytic cracking processes. Therefore, these methods can significantly improve the production efficiency of aromatic hydrocarbons and olefins, compared to conventional methods. As shown in fig. 2, embodiments of the present invention include a method of producing aromatic hydrocarbons and/or olefins. As shown in fig. 1, the method 200 may be carried out by the reaction apparatus 100.
According to an embodiment of the present invention, as shown in block 201, the process 200 may include contacting naphtha with catalyst particles in a dense phase riser reactor 101 under reaction conditions sufficient to produce a catalyst composition comprising one or more than one aromatic hydrocarbon and/or one or more than one olefin. In an embodiment of the invention, the contacting of block 201 comprises injecting a lift gas into the dense phase riser reactor 101 through the lift gas inlet 104, naphtha through the feed inlet 103, and/or catalyst through the catalyst inlet 105 such that the catalyst particles and naphtha contact each other and the material in the dense phase riser reactor 101 moves upward. In an embodiment of the invention, the naphtha of the contacting step of block 201 comprises hydrocarbons having a final boiling point of less than 350 ℃. In embodiments of the present invention, the first reaction conditions of block 201 may include a Superficial Gas Velocity (SGV) of from 4m/s to 20m/s and all ranges and values therebetween, including 4m/s to 5m/s, 5m/s to 6m/s, 6m/s to 7m/s, 7m/s to 8m/s, 8m/s to 9m/s, 9m/s to 10m/s, 10m/s to 11m/s, 11m/s to 12m/s, 12m/s to 13m/s, 13m/s to 14m/s, 14m/s to 15m/s, 15m/s to 16m/s, 16m/s to 17m/s, 17m/s to 18m/s, 18m/s to 19m/s, and 19m/s to 20 m/s. The reaction conditions of block 201 may include reaction temperatures of 670 ℃ to 730 ℃ and all values and ranges therebetween, including 670 ℃ to 675 ℃, 675 ℃ to 680 ℃, 680 ℃ to 685 ℃, 685 ℃ to 690 ℃, 690 ℃ to 695 ℃, 695 ℃ to 700 ℃, 700 ℃ to 705 ℃, 705 ℃ to 710 ℃, 710 ℃ to 710 ℃715 ℃, 715 ℃ to 720 ℃, 720 ℃ to 755 ℃, and 725 ℃ to 730 ℃. The reaction conditions of block 201 may also include reaction pressures of 1 bar to 3 bar and all ranges and values therebetween, including 1 bar to 1.5 bar, 1.5 bar to 2.0 bar, 2.0 bar to 2.5 bar, and 2.5 bar to 3.0 bar. The reaction conditions of block 201 may also include an average residence time in the dense phase riser reactor 101 of all ranges and values between and from 1s to 3s, including 1s to 1.5s, 1.5s to 2.0s, 2.0s to 2.5s, and 2.5s to 3.0 s. The reaction conditions at block 201 may also include 0.3hr-1To 3hr-1And weight hourly space velocity of all ranges and values therebetween, including 0.3hr-1To 0.6hr-1、0.6hr-1To 0.9hr-1、0.9hr-1To 1.2hr-1、1.2hr-1To 1.5hr-1、1.5hr-1To 1.8hr-1、1.8hr-1To 2.1hr-1、2.1hr-1To 2.4hr-1、2.4hr-1To 2.7hr-1And 2.7hr-1To 3.0hr-1。
According to embodiments of the present invention, in block 201, the fluidized catalyst bed in the dense phase riser reactor 101 may have a Solids Volume Fraction (SVF) in the range of from 0.1 to 0.2 and all ranges and values therebetween, including from 0.11 to 0.12, from 0.12 to 0.13, from 0.13 to 0.14, from 0.14 to 0.15, from 0.15 to 0.16, from 0.16 to 0.17, from 0.17 to 0.18, from 0.18 to 0.19, and from 0.19 to 0.20. According to an embodiment of the present invention, the catalyst of the dense phase riser reactor 101 comprises a zeolite. In block 201, each dense phase riser reactor 101 may be at 120kg/m3To 240kg/m3And all ranges and values therebetween, including 120kg/m3To 130kg/m3、130kg/m3To 140kg/m3、140kg/m3To 150kg/m3、150kg/m3To 160kg/m3、160kg/m3To 170kg/m3、170kg/m3To 180kg/m3、180kg/m3To 190kg/m3、190kg/m3To 200kg/m3、200kg/m3To 210kg/m3、210kg/m3To 220kg/m3、220kg/m3To 230kg/m3And 230kg/m3To 240kg/m3。
In block 201, lift gas and naphtha are flowed into a dense phase riser reactor in a volumetric ratio of 0.4 to 0.8 and all ranges and values therebetween, including 0.4 to 0.5, 0.5 to 0.6, 0.6 to 0.7, and 0.7 to 0.8, according to an embodiment of the present invention. Each dense phase riser reactor 101 can comprise a catalytic bed having a catalyst-to-oil ratio of 10 to 50 (on a weight basis) and all ranges and values therebetween, including 10 to 12, 12 to 14, 14 to 16, 16 to 18, 18 to 20, 20 to 22, 22 to 24, 24 to 26, 26 to 28, 28 to 30, 30 to 32, 32 to 34, 34 to 36, 36 to 38, 38 to 40, 40 to 42, 42 to 44, 44 to 46, 46 to 48, and 48 to 50.
According to an embodiment of the invention, the method 200 further includes flowing the effluent from each dense phase riser reactor 101, including a mixture of first product, catalyst particles, and unreacted naphtha, to a cyclone system disposed in the secondary reactor 107, as shown in block 202. The effluent from each dense phase riser reactor 101 can further comprise a lift gas. In an embodiment of the invention, the flow at block 202 is facilitated by a lift gas. Non-limiting examples of the lift gas may include nitrogen, methane, any inert gas, steam, or combinations thereof.
According to an embodiment of the invention, the method 200 may further include separating the first product from the catalyst particles in a cyclone system of the secondary reactor 107, as shown in block 203. In an embodiment of the invention, the separation of block 203 comprises a gas-solid separation to produce a gaseous product stream and a solid catalyst stream. According to an embodiment of the invention, the gaseous product stream comprises the first product. In an embodiment of the invention, the first product comprises unreacted naphtha, BTX (benzene, toluene, xylene), lower olefins (C)2And C3Olefins), lift gas, by-products, or combinations thereof. The first product can have a weight ratio of BTX to lower olefins of 0.25 to 0.45 and all ranges and values therebetween, including 0.25 to 0.30, 0.30 to 0.35, 0.35 to 0.40, and 0.40 to 0.45. Yields of BTX can be 13% to 17% and all ranges and values therebetween, including 13% to 14%, 14% to 15%, 15% to 16%, and 16% to 17%. The separation of block 203 may beIncluding passing the effluent of the dense phase riser reactor 101 through one or more cyclones of the secondary reactor 107. In an embodiment of the invention, the product gas stream comprises 13 to 17 wt.% BTX.
According to an embodiment of the invention, method 200 includes stripping hydrocarbon vapors from catalyst particles in a stripper 111 disposed in regenerator 110 to produce stripped catalyst particles, as shown at block 204. In an embodiment of the invention, hydrocarbon vapors are adsorbed on the catalyst particles prior to stripping at block 204. In embodiments of the invention, in block 204, the volume ratio of stripping gas to catalyst particles is from 0.02 to 0.65 and all ranges and values therebetween, including from 0.02 to 0.05, from 0.05 to 0.08, from 0.08 to 0.11, from 0.11 to 0.14, from 0.14 to 0.17, from 0.17 to 0.20, from 0.20 to 0.23, from 0.23 to 0.26, from 0.26 to 0.29, from 0.29 to 0.32, from 0.32 to 0.35, from 0.35 to 0.38, from 0.38 to 0.41, from 0.41 to 0.44, from 0.44 to 0.47, from 0.47 to 0.50, to 0.53, from 0.53 to 0.56, from 0.56 to 0.59, from 0.59 to 0.62, and from 0.62 to 0.65.
According to an embodiment of the invention, as shown in block 205, the method 200 includes regenerating the stripped catalyst particles in the regenerator 110. In an embodiment of the present invention, in block 205, the catalyst particles are regenerated in the presence of air. The regeneration of block 205 may be performed at a regeneration temperature of 680 ℃ to 750 ℃ and all ranges and values therebetween, including 680 ℃ to 690 ℃, 690 ℃ to 700 ℃, 700 ℃ to 710 ℃, 710 ℃ to 720 ℃, 720 ℃ to 730 ℃, 730 ℃ to 740 ℃, and 740 to 750 ℃. In an embodiment of the invention, the regeneration at block 205 produces regenerated catalyst and flue gas. The flue gas may be separated from the regenerated catalyst in the cyclone 118. In an embodiment of the present invention, regenerated catalyst flows to each dense phase riser reactor 101 through catalyst outlet 117.
Although embodiments of the present invention are described with reference to the blocks in fig. 2, it should be understood that the operations of the present invention are not limited to the specific blocks and/or the specific order of the blocks illustrated in fig. 2. Thus, embodiments of the invention may use different blocks in a different order than that of FIG. 2 to provide the functionality described herein.
Specific examples are included as part of the disclosure of the invention. The examples are for illustrative purposes only and are not intended to limit the present invention. One of ordinary skill in the art will readily recognize parameters that may be varied or varied to produce substantially the same results.
Examples
Example 1
(preparation of BTX and Low carbon olefins by catalytic cracking)
Experiments for the preparation of BTX and lower olefins by catalytic cracking were conducted in the pilot plant of the present invention. The dense phase riser reactor in the pilot scale reactor was operated at high volume fraction of solids and high back mixing to maximize aromatic yield. The composition of the raw materials used in these experiments is shown in table 1.
TABLE 1 composition of the raw materials
The reaction conditions of the reaction apparatus include: the reaction temperature is 680 ℃, the catalyst regeneration temperature is 700 ℃, the reaction pressure is 1.50atm, the catalyst-oil ratio is 30, and the Weight Hourly Space Velocity (WHSV) is 1.9h-1And a catalyst loading of 1500 g. The results of the experiment are shown in table 2.
TABLE 2 results of different reactor pilot plants
The results show that high BTX yields can be obtained in reactors operated under conditions including short contact times, high volume fractions of solids, and high back-mixing in the reactor.
In the context of the present invention, at least the following 17 embodiments are described. Embodiment 1 is a process for producing aromatic hydrocarbons. The process comprises contacting naphtha and catalyst particles in a dense phase riser reactor under conditions sufficient to produce a first product comprising one or more than one olefin and/or one or more than one aromatic hydrocarbon, wherein the dense phase riser reactor is in the dense phase riser reactorOperating at a superficial gas velocity of between 4m/s and 20 m/s. The process also includes flowing a mixture of the first product, catalyst particles, and unreacted naphtha to a cyclone system disposed in a secondary reactor, wherein the secondary reactor is stacked on top of the regenerator. The method also includes separating the first product from the catalyst particles in a cyclone system. The method also includes, in a stripper of the regenerator, stripping hydrocarbon vapors from the catalyst particles to produce stripped catalyst particles, and regenerating the stripped catalyst particles in the regenerator. Embodiment 2 is the process of embodiment 1, wherein the dense phase riser reactor has an inner diameter of 2.0m to 2.75 m. Embodiment 3 is the method of any of embodiments 1 or 2, wherein the dense phase riser reactor comprises a fluidized bed having a volume fraction of Solids (SVF) of 0.1 to 0.2. Embodiment 4 is the process of any of embodiments 1 to 3, wherein the stripping column and the regenerator are operated with a plurality of dense phase riser reactors. Embodiment 5 is the process of any one of embodiments 1 to 4, wherein the one or more dense phase riser reactors are operated using a lift gas selected from the group consisting of nitrogen, methane, any inert gas, and combinations thereof. Embodiment 6 is the process of embodiment 5, wherein the lift gas contains 10 wt.% steam. Embodiment 7 is the method of any one of embodiments 1 to 6, wherein the catalyst contains particles having an average diameter of 75 μm to 120 μm. Embodiment 8 is the method of any one of embodiments 1 to 7, wherein the catalyst has a particle density of 1000kg/m3To 1400kg/m3. Embodiment 9 is the method of any one of embodiments 1 to 8, wherein the first product comprises unreacted naphtha, aromatic hydrocarbons, lower olefins, lift gas, byproducts, or a combination thereof. Embodiment 10 is the method of any one of embodiments 1 to 9, wherein the reaction conditions include a reaction temperature of 670 ℃ to 730 ℃. Embodiment 11 is the method of any one of embodiments 1 to 10, wherein the reaction conditions include 0.3hr-1To 3hr-1And an average residence time of 1s to 5 s. Embodiment 12 is the process of any of embodiments 1 to 11, wherein the dense phase riser reactor comprises a fluidized bed having a weight ratio of agent oil of 10 to 50. Embodiment 13 is any one of embodiments 1 to 12The process of (1), wherein the dense phase riser reactor is operated at a feed to lift gas volume ratio of from 1.25 to 2.5.
Example 14 is a reaction apparatus for producing aromatic hydrocarbons. The reaction apparatus comprises one or more dense phase riser reactors, wherein each dense phase riser reactor comprises a shell and a feed inlet in the lower half of the shell adapted to receive feed into the shell. The reaction apparatus also includes a lift gas inlet at the bottom of the shell adapted to receive lift gas into the shell. The reactor apparatus also includes a catalyst inlet at the bottom of the housing adapted to receive catalyst into the housing. The reactor apparatus also includes an outlet at the top of the housing adapted to release the effluent of the dense phase riser from the housing. Further, the reaction apparatus comprises a secondary reactor in fluid communication with the outlet of each dense phase riser reactor, wherein the secondary reactor comprises one or more cyclones adapted to separate the effluent of the one or more dense phase risers into a gaseous stream comprising gaseous products and a solid stream comprising catalyst. The reaction apparatus further comprises a regenerator in fluid communication with the secondary reactor, the regenerator adapted to receive a flow of solids from the secondary reactor and regenerate catalyst in the flow of solids, wherein the secondary reactor is stacked on top of the regenerator and the regenerator is in fluid communication with the catalyst inlet of each dense phase riser reactor. Embodiment 15 is the reaction unit of embodiment 14, wherein the catalyst regeneration unit further comprises a stripper adapted to strip hydrocarbons adsorbed on the catalyst particles of the solid stream using a stripping gas prior to catalyst regeneration. Embodiment 16 is the reaction apparatus of embodiment 15, wherein the stripping gas comprises nitrogen, methane, flue gas, or a combination thereof. Embodiment 17 is the reaction apparatus of any one of embodiments 14 to 16, wherein the regenerator further comprises one or more than one cyclone suitable for separating flue gas from the catalyst.
Although embodiments of the present application and their advantages have been described in detail, it should be understood that various changes, substitutions and alterations can be made herein without departing from the embodiments as defined by the appended claims. Moreover, the scope of the present application is not intended to be limited to the particular embodiments of the process, machine, manufacture, composition of matter, means, methods and steps described in the specification. As one of ordinary skill in the art will readily appreciate from the disclosure, processes, machines, manufacture, compositions of matter, means, methods, or steps, presently existing or later to be developed that perform substantially the same function or achieve substantially the same result as the corresponding embodiments described herein may be utilized. Accordingly, the appended claims are intended to include within their scope such processes, machines, manufacture, compositions of matter, means, methods, or steps.
Claims (20)
1. A method of producing aromatic hydrocarbons, the method comprising:
contacting naphtha and catalyst particles in a dense phase riser reactor under conditions sufficient to produce a first product comprising one or more than one olefin and/or one or more than one aromatic hydrocarbon, wherein the dense phase riser reactor is operated at a superficial gas velocity of from 4m/s to 20 m/s;
passing a mixture of the first product, catalyst particles, and unreacted naphtha to a cyclone system disposed in a secondary reactor, wherein the secondary reactor is stacked on top of the regenerator;
separating the first product from the catalyst particles in a cyclone system;
stripping hydrocarbon vapors from the catalyst particles in a stripper disposed in the regenerator to produce stripped catalyst particles; and
the stripped catalyst particles are regenerated in a regenerator.
2. The process of claim 1, wherein the dense phase riser reactor has an internal diameter of 2.0m to 2.75 m.
3. The method of any of claims 1-2, wherein the dense phase riser reactor comprises a fluidized bed having a Solids Volume Fraction (SVF) of 0.1 to 0.2.
4. The process of any of claims 1-2, wherein the stripping column and regenerator are operated with a plurality of dense phase riser reactors.
5. The process of any of claims 1-2, wherein one or more dense phase riser reactors operate using a lift gas selected from the group consisting of nitrogen, methane, any inert gas, and combinations thereof.
6. The method of claim 5, wherein the lift gas contains less than 10 wt% steam.
7. The process of any one of claims 1 to 2, wherein the catalyst comprises particles having an average diameter of from 75 μ ι η to 120 μ ι η.
8. The process according to any one of claims 1 to 2, wherein the catalyst has a particle density of 1000kg/m3To 1400kg/m3。
9. The method of any one of claims 1-2, wherein the first product comprises unreacted naphtha, aromatic hydrocarbons, lower olefins, lift gas, byproducts, or a combination thereof.
10. The process of any one of claims 1 to 2, wherein the reaction conditions comprise a reaction temperature of 670 ℃ to 730 ℃.
11. The method of any one of claims 1 to 2, wherein reaction conditions include 0.3hr-1To 3hr-1And an average residence time of 1s to 5 s.
12. The process of any of claims 1-2, wherein the dense phase riser reactor comprises a fluidized bed having a weight ratio of agent to oil of 10 to 50.
13. The process of any of claims 1-2, wherein the dense phase riser reactor operates at a volumetric ratio of feed to lift gas of 1.25 to 2.5.
14. A reaction apparatus for producing aromatic hydrocarbons, the reaction apparatus comprising:
one or more than one dense phase riser reactor, wherein each dense phase riser reactor comprises:
a housing;
a feed inlet disposed in the lower half of the housing and adapted to receive feed material into the housing;
a lift gas inlet at the bottom of the shell adapted to receive lift gas into the shell;
a catalyst inlet at the bottom of the housing adapted to receive catalyst into the housing;
an outlet at the top of the housing adapted to release the effluent of the dense phase riser from the housing;
a secondary reactor in fluid communication with the outlet of each dense phase riser reactor, wherein the secondary reactor comprises one or more cyclones adapted to separate the effluent of the dense phase riser into a gas stream comprising gaseous products and a solids stream comprising catalyst; and
a regenerator in fluid communication with the secondary reactor adapted to receive the solids stream from the secondary reactor and regenerate the catalyst of the solids stream, wherein the secondary reactor is stacked on top of the regenerator and the regenerator is in fluid communication with the catalyst inlet of each dense phase riser reactor.
15. The reactor of claim 14, wherein the catalyst regeneration unit further comprises a stripper adapted to strip hydrocarbons adsorbed on catalyst particles of the solid stream using a stripping gas prior to catalyst regeneration.
16. The reaction device of claim 15, wherein the stripping gas comprises nitrogen, methane, flue gas, or a combination thereof.
17. The reactor apparatus of claim 14 wherein the regenerator further comprises one or more cyclones adapted to separate flue gas from catalyst.
18. The reactor apparatus of claim 15 wherein the regenerator further comprises one or more cyclones adapted to separate flue gas from catalyst.
19. The reactor apparatus of claim 16 wherein the regenerator further comprises one or more cyclones adapted to separate flue gas from catalyst.
20. The process of claim 3, wherein the dense phase riser reactor is operated at a feed to lift gas volume ratio of 1.25 to 2.5.
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| US201962883069P | 2019-08-05 | 2019-08-05 | |
| US62/883,069 | 2019-08-05 | ||
| PCT/IB2020/057226 WO2021024117A1 (en) | 2019-08-05 | 2020-07-30 | Multiple dense phase risers to maximize aromatics yields for naphtha catalytic cracking |
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| US (1) | US20220275286A1 (en) |
| EP (1) | EP3990580A1 (en) |
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| WO (1) | WO2021024117A1 (en) |
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| US20150337207A1 (en) * | 2012-01-06 | 2015-11-26 | Shell Oil Company | Process for making a distillate product and/or c2-c4 olefins |
| US10344220B2 (en) * | 2015-10-21 | 2019-07-09 | Hindustan Petroleum Corporation Ltd. | Methods and apparatus for fluid catalytic cracking |
| WO2018116085A1 (en) * | 2016-12-19 | 2018-06-28 | Sabic Global Technologies B.V. | Process integration for cracking light paraffinic hydrocarbons |
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2020
- 2020-07-30 US US17/626,201 patent/US20220275286A1/en active Pending
- 2020-07-30 WO PCT/IB2020/057226 patent/WO2021024117A1/en unknown
- 2020-07-30 EP EP20753443.9A patent/EP3990580A1/en active Pending
- 2020-07-30 CN CN202080065439.6A patent/CN114423845A/en active Pending
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| US3353925A (en) * | 1962-05-23 | 1967-11-21 | Exxon Research Engineering Co | Apparatus for conversion of hydrocarbons |
| US4422925A (en) * | 1981-12-28 | 1983-12-27 | Texaco Inc. | Catalytic cracking |
| US4428822A (en) * | 1982-04-26 | 1984-01-31 | Texaco Inc. | Fluid catalytic cracking |
| CN102046756A (en) * | 2008-05-29 | 2011-05-04 | 凯洛格·布朗及鲁特有限责任公司 | FCC for light feed upgrading |
| CN103131464A (en) * | 2011-11-23 | 2013-06-05 | 中国石油化工股份有限公司 | Hydrocarbon catalytic conversion method for producing low carbon olefin and light aromatic hydrocarbon |
| CN107828443A (en) * | 2016-09-16 | 2018-03-23 | 鲁姆斯科技公司 | For making the fluidized catalytic cracking method and device of light olefins yields maximization and other application |
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| EP3990580A1 (en) | 2022-05-04 |
| US20220275286A1 (en) | 2022-09-01 |
| WO2021024117A1 (en) | 2021-02-11 |
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