CN112745914A

CN112745914A - Integrated method and integrated device for converting crude oil into petrochemical products

Info

Publication number: CN112745914A
Application number: CN201911046105.XA
Authority: CN
Inventors: 马文明; 朱根权; 杨超; 毛安国
Original assignee: Sinopec Research Institute of Petroleum Processing; China Petroleum and Chemical Corp
Current assignee: Sinopec Research Institute of Petroleum Processing; China Petroleum and Chemical Corp
Priority date: 2019-10-30
Filing date: 2019-10-30
Publication date: 2021-05-04
Anticipated expiration: 2039-10-30
Also published as: CN112745914B

Abstract

The invention provides an integrated method and an integrated device for converting crude oil into petrochemical products. The integration method comprises the following steps: carrying out flash separation on the crude oil to obtain a light component, a medium component and a heavy component; introducing the light components into a cracking furnace for thermal cracking to obtain a thermal cracking product; introducing the medium component and the heavy component into a catalytic cracking device, and respectively contacting with a cracking catalyst for reaction to obtain an oil-gas mixture; introducing the thermal cracking products and the oil-gas mixture into the separation system for separation. The integration method and the integration device can save energy consumption and improve the yield of low-carbon olefins such as ethylene and propylene and light aromatic hydrocarbons such as benzene, toluene, xylene and ethylbenzene.

Description

Integrated method and integrated device for converting crude oil into petrochemical products

Technical Field

The invention relates to the field of petroleum processing, in particular to an integrated method and an integrated device for converting crude oil into petrochemical products.

Background

Crude oil is a complex mixture of many hydrocarbons. At present, oil refineries mainly convert crude oil into fuels such as gasoline, kerosene and diesel oil, and simultaneously produce ethylene, propylene and BTX (benzene, toluene and xylene are abbreviated as BTX). With the rapid development of new energy vehicles, for example, the great support of various countries on electric vehicles, the annual growth rate of vehicle fuel demand is gradually decreasing, and fuels such as gasoline, kerosene and diesel oil face the trend of excess capacity, which has a certain influence on the energy expansion and reconstruction of oil refineries. Petrochemical products such as ethylene, propylene, and BTX have a very wide range of applications, and in recent years, the annual growth rate of demand has been greater than that of production, and a situation of short supply has arisen in the market. Therefore, a set of integration technology needs to be developed on the basis of the existing oil refining device to achieve the purposes of reducing the yield of fuels such as gasoline, kerosene and diesel oil and simultaneously improving the yield of petrochemical products such as ethylene, propylene and BTX.

US 3702292 discloses an integrated arrangement for crude oil refining for the production of fuels and chemicals, in which process the integrated arrangement comprises a crude oil distillation unit, a hydrocracking unit, a reforming unit, a steam thermal cracking unit, a catalytic cracking unit, an aromatics recovery unit, a butadiene recovery unit, an alkylation unit and a delayed coking unit, with which integrated arrangement 50 w% conversion of the fuel and 50 w% conversion of the petrochemicals to crude oil can be obtained.

CN 106029610 discloses an integrated process and installation for converting crude oil into petrochemicals. The integrated process in the process comprises crude oil distillation, hydrocracking, aromatization and olefin synthesis, and the facilities in the process comprise a crude oil distillation unit, a hydrocracking unit, an aromatization unit and an olefin synthesis unit. The process and plant have improved ethylene and BTX yields while being able to maintain good carbon rates in the conversion of crude oil to petrochemicals. In addition, 32.3 w% ethylene and 41.4 w% BTX for the weight of the feed can be obtained using this integrated process.

Although the technology can separate and treat crude oil through different unit operations to obtain petrochemical products with higher yield, the integration method is more complex, the unit operations are more, and crude oil distillation towers are arranged, so that more energy is consumed.

It is noted that the information disclosed in the foregoing background section is only for enhancement of background understanding of the invention and therefore it may contain information that does not constitute prior art that is already known to a person of ordinary skill in the art.

Disclosure of Invention

Aiming at the defects of the prior art, the invention provides an integrated method for converting crude oil into petrochemical products, which can obviously improve the yield of low-carbon olefins and light aromatics.

In order to achieve the purpose, the invention adopts the following technical scheme:

an integrated process for converting crude oil to petrochemical products comprising:

carrying out flash separation on the crude oil to obtain a light component, a medium component and a heavy component;

introducing the light components into a cracking furnace for thermal cracking to obtain a thermal cracking product;

introducing the medium component and the heavy component into a catalytic cracking device, and respectively contacting with a cracking catalyst for reaction to obtain an oil-gas mixture;

introducing the thermal cracking products and the oil-gas mixture into the separation system for separation.

In some embodiments, the catalytic cracking unit comprises a first riser reactor, a first fluidized bed reactor, and a second fluidized bed reactor, wherein the reaction of the medium components and the heavy components in the catalytic cracking unit comprises: introducing the medium component into the first fluidized bed reactor and contacting with the cracking catalyst for reaction to obtain a first oil agent mixture; introducing the heavy component into the first riser reactor and contacting with the cracking catalyst for reaction to obtain a second oil agent mixture; and introducing the first oil mixture and the second oil mixture into the second fluidized bed reactor for reaction, and separating to obtain the oil-gas mixture.

In some embodiments, the method further comprises separating the first oil mixture to obtain spent catalyst, and introducing the spent catalyst into the first riser reactor.

In some embodiments, the reaction conditions of the first fluidized bed reactor are: the reaction temperature is 580-720 ℃, the preferable temperature is 620-670 ℃, and the weight hourly space velocity is 1-30 hours^-1Preferably 3 to 10 hours^-1The pressure in the reactor is 0.1-0.4 MPa, preferably 0.15-0.3 MPa; the reaction temperature of the first riser reactor is 480-620 ℃, the preferable temperature is 520-600 ℃, the agent-oil ratio is 2-25, the preferable temperature is 3-20, and the reaction time is 1-15 seconds, the preferable time is 2-10 seconds; the reaction temperature of the second fluidized bed reactor is 520-700 ℃, preferably 580-650 ℃, and the weight hourly space velocity is 1-30 hours^-1Preferably 5 to 20 hours^-1The pressure in the reactor is 0.1 to 0.4MPa, preferably 0.15 to 0.3 MPa.

In some embodiments, the cracking catalyst contains a cracking active component, a clay and a binder, the cracking active component comprises a molecular sieve with an MFI structure, the clay is selected from one or more of kaolin, montmorillonite and bentonite, the binder is selected from one or more of silica sol, alumina sol and pseudo-boehmite, and the content of the cracking active component is 20-70 wt%, preferably 30-50 wt% based on the dry weight of the cracking catalyst; the content of the clay is 15-60 wt%, preferably 30-50 wt%; the content of the binder is 20-35 wt%, preferably 20-30 wt%.

In some embodiments, the cracking active component comprises an optional Y molecular sieve and an optional β molecular sieve, wherein the content of the Y molecular sieve is 0 to 90 wt%, preferably 50 to 80 wt%, the content of the molecular sieve having an MFI structure is 1 to 50 wt%, preferably 10 to 40 wt%, and the content of the β molecular sieve is 0 to 50 wt%, preferably 10 to 40 wt%, based on the total weight of the cracking active component.

In some embodiments, the thermal cracking product and the oil-gas mixture are separated by the separation system to obtain gas, ethylene, propylene, ethane, propane, C4 hydrocarbons, light gasoline, heavy gasoline, diesel oil and slurry oil.

In some embodiments, the method further comprises introducing ethane and propane into the cracking furnace, wherein the reaction temperature of the thermal cracking is 750-900 ℃, preferably 780-880 ℃, the reaction pressure is 0-175 kPa, preferably 50-150 kPa, and the residence time is 0.05-1 second, preferably 0.1-0.5 second.

In some embodiments, the method further comprises introducing the heavy gasoline into a gasoline hydrogenation unit for hydrotreating to obtain hydrogenated gasoline, wherein the hydrotreating reaction conditions are as follows: the reaction temperature is 200-350 ℃, and the volume space velocity is 1-5 hours^-1The volume ratio of hydrogen to oil is 100-400 Nm³/m³。

In some embodiments, further comprising separating the hydrogenated gasoline to obtain C5 hydrocarbons, C6-C8 hydrocarbons, and C9 and greater hydrocarbons.

In some embodiments, the method further comprises an extraction treatment of the C6-C8 hydrocarbon to obtain raffinate oil and light aromatic hydrocarbons, wherein the extraction treatment is performed in an extraction tower, a solvent of the extraction treatment is one or more of sulfolane, N-methylpyrrolidone, dimethyl sulfoxide and formylmorpholine, preferably sulfolane, the content of water in the solvent is 0.5-2 wt%, preferably 0.7-1.2 wt%, and the mass ratio of the solvent to the C6-C8 hydrocarbon is 2-5, preferably 3-4; the temperature of the top of the extraction tower is 80-100 ℃, preferably 85-95 ℃, the temperature of the bottom of the extraction tower is 170-190 ℃, preferably 175-185 ℃, and the pressure is 0.2-0.6 MPa, preferably 0.4-0.55 MPa.

In some embodiments, the method further comprises introducing the raffinate oil into a reformer for reforming, wherein the reaction conditions of the reforming are as follows: the reaction temperature is 450-550 ℃ and the volume space velocity is 1-10 hours^-1The volume ratio of hydrogen to oil is 1-10 Nm³/m³And the reaction pressure is 0.2-1.0 MPa。

In some embodiments, further comprising introducing the C9 plus hydrocarbons and the diesel to a diesel hydrotreater for hydrotreating to yield hydrogenated diesel, and introducing the hydrogenated diesel and the C5 hydrocarbons to the first fluidized bed reactor.

In some embodiments, the catalytic cracking apparatus comprises a second riser reactor, and the integrated method further comprises introducing the C4 hydrocarbon and the light gasoline into the second riser reactor to contact with the cracking catalyst for reaction, and introducing the reacted oil mixture into the second fluidized bed reactor, wherein the reaction temperature of the second riser reactor is 560 to 720 ℃, preferably 580 to 680 ℃, the ratio of the oil to the agent is 3 to 40, preferably 5 to 30, and the reaction time is 0.5 to 10 seconds, preferably 1 to 5 seconds.

In some embodiments, the crude oils include paraffinic, meso, and naphthenic base crude oils.

In some embodiments, the flash separation comprises subjecting the crude oil to a first flash treatment resulting in the light and medium heavy components; and carrying out second flash evaporation treatment on the medium heavy component to obtain the medium component and the heavy component, wherein the temperature of the first flash evaporation treatment is 50-80 ℃, preferably 50-65 ℃, the pressure is 0.1-0.3 MPa, preferably 0.12-0.2 MPa, and the cutting point of the light component and the medium heavy component is 40-60 ℃, preferably 40-50 ℃; the temperature of the second flash evaporation treatment is 200-300 ℃, preferably 220-250 ℃, the pressure is 0.1-0.3 MPa, preferably 0.12-0.2 MPa, and the cutting point of the medium component and the heavy component is 210-240 ℃, preferably 220-230 ℃.

In some embodiments, before the flash separation, the crude oil is further subjected to an electric desalting treatment, wherein the temperature of the electric desalting treatment is 80-200 ℃, preferably 100-150 ℃, the pressure is 0.1-0.5 MPa, preferably 0.1-0.3 MPa, the water injection amount is 1-10 wt%, preferably 3-8 wt%, and the electric field strength is 200-1000V/cm, preferably 400-800V/cm.

In another aspect, the present invention provides an integrated apparatus for converting crude oil into petrochemical products, comprising:

a flash tank;

a cracking furnace;

a catalytic cracking unit; and

the separation system is used for separating the liquid from the liquid,

the feed end of the cracking furnace and the feed end of the catalytic cracking device are respectively communicated with the discharge end of the flash tank, the discharge end of the cracking furnace and the discharge end of the catalytic cracking device are respectively communicated with the feed end of the separation system, crude oil passes through the flash tank to obtain a light component, a medium component and a heavy component, and the light component enters the cracking furnace to obtain a thermal cracking product; and the medium component and the heavy component respectively enter the catalytic cracking device to carry out cracking reaction to obtain an oil-gas mixture, and the thermal cracking product and the oil-gas mixture are separated in the separation system.

In some embodiments, the catalytic cracking apparatus comprises a first riser reactor, a first fluidized bed reactor, and a second fluidized bed reactor, the first riser reactor and the first fluidized bed reactor being in communication with the second fluidized bed reactor, respectively, and a discharge end of the second fluidized bed reactor being in communication with a feed end of the separation system.

In some embodiments, the catalytic cracking apparatus further comprises a second riser reactor, the second riser reactor being in communication with the second fluidized bed reactor, and a feed end of the second riser reactor being in communication with a discharge end of the separation system for receiving and processing the C4 hydrocarbons and light gasoline separated by the separation system.

In some embodiments, the first riser reactor and the second riser reactor are each independently selected from one or more of an equal diameter riser reactor, an equal linear velocity riser reactor, and a variable diameter riser reactor; the first fluidized bed reactor is selected from the group consisting of a fixed fluidized bed reactor, a bulk fluidized bed reactor, a bubbling bed reactor, a turbulent bed reactor, a fast bed reactor, a transport bed reactor, and a dense phase fluidized bed reactor, each independently.

In some embodiments, the flash tank comprises a first flash tank and a second flash tank, the discharge end of the first flash tank is in communication with the feed end of the cracking furnace and the feed end of the second flash tank, and the feed end of the first riser reactor and the feed end of the first fluidized bed reactor are in communication with the discharge end of the second flash tank, respectively.

In some embodiments, further comprising an electric desalter, a discharge end of the electric desalter being in communication with a feed end of the first flash tank.

In some embodiments, the system further comprises a gasoline hydrogenation device, wherein a feed end of the gasoline hydrogenation device is communicated with a discharge end of the separation system, and is used for receiving and processing the heavy gasoline separated by the separation system to obtain hydrogenated gasoline.

In some embodiments, the system further comprises a hydrogenated gasoline separation device, wherein the feed end of the hydrogenated gasoline separation device is communicated with the discharge end of the gasoline hydrogenation device and is used for receiving and separating the hydrogenated gasoline.

In some embodiments, the system further comprises an extraction device, wherein a feed end of the extraction device is communicated with a discharge end of the hydrogenated gasoline separation device, and the extraction device is used for receiving and processing the C6-C8 hydrocarbons separated by the hydrogenated gasoline separation device to obtain raffinate oil and light aromatic hydrocarbons.

In some embodiments, the device further comprises a reforming device, wherein the feeding end of the reforming device is communicated with the discharging end of the extraction device and is used for receiving and processing the raffinate oil.

In some embodiments, the device further comprises a diesel hydrogenation device, a feed end of the diesel hydrogenation device is communicated with the discharge end of the separation system and one discharge end of the hydrogenated gasoline separation device, and is used for receiving and processing the diesel separated by the separation system and the hydrocarbons above C9 separated by the hydrogenated gasoline separation device, and the discharge end of the diesel hydrogenation device and the other discharge end of the hydrogenated gasoline separation device are respectively communicated with the feed end of the catalytic cracking device.

The integrated method and the integrated device can save energy consumption and improve the yield of light aromatic hydrocarbons such as ethylene, propylene, benzene, toluene, xylene, ethylbenzene and the like.

Drawings

FIG. 1 is a schematic material flow diagram of an integrated process according to one embodiment of the present invention;

FIG. 2 is a schematic structural diagram of an integrated device according to an embodiment of the present invention;

wherein the reference numerals are as follows:

11-crude oil

1-electric desalination apparatus

12-stripped crude oil

2-first flash tank

21-light component

22-medium heavy component

3-second flash tank

31-mesogenic component

32-heavy component

4-catalytic cracking unit

4-1-first fluidized bed reactor

4-2-first riser reactor

4-3-second riser reactor

4-4-second fluidized bed reactor

4-5-stripper

4-6-settler

4-7-regenerator

41-first fluidized bed reactor feed

42-first fluidized bed reactor discharge

43-reaction oil gas

44-regeneration of air

45-regeneration flue gas

5-cracking furnace

51-thermal cracking product 6-separation system

60-gas

61-ethylene

62-ethane

63-propene

64-propane

65-C4 hydrocarbons

66-light gasoline

67-heavy gasoline

68-diesel oil

69-oil slurry

7-11-liquid product treatment unit 7-gasoline hydrogenation device

71-hydrogenated gasoline

8-hydrogenation gasoline separation device

81-hydrogenation gasoline separation feed

82-C6-C8 hydrocarbons

Hydrocarbons above 83-C9

84-C5 hydrocarbons

9-extraction device

91-raffinate oil

92-light aromatic hydrocarbons

10-reformer

101-reformate

11-diesel hydrogenation device

111-diesel hydrogenation feed

112-hydrogenated diesel oil

Detailed Description

The technical solution of the present invention is further explained below according to specific embodiments. The scope of protection of the invention is not limited to the following examples, which are set forth for illustrative purposes only and are not intended to limit the invention in any way.

In the present invention, anything or matters not mentioned is directly applicable to those known in the art without any change except those explicitly described. Moreover, any embodiment described herein may be freely combined with one or more other embodiments described herein, and the technical solutions or ideas thus formed are considered part of the original disclosure or original description of the present invention, and should not be considered as new matters not disclosed or contemplated herein, unless a person skilled in the art would consider such combination to be clearly unreasonable.

All features disclosed in this invention may be combined in any combination and such combinations are understood to be disclosed or described herein unless a person skilled in the art would consider such combinations to be clearly unreasonable. The endpoints of the ranges and any values disclosed herein are not limited to the precise range or value, and such ranges or values should be understood to encompass values close to those ranges or values. For ranges of values, between the endpoints of each of the ranges and the individual points, and between the individual points may be combined with each other to give one or more new ranges of values, and these ranges of values should be considered as specifically disclosed herein.

The present invention provides an integrated method and an integrated apparatus for converting crude oil into petrochemical products, wherein fig. 1 is a schematic material flow diagram of the integrated method according to an embodiment of the present invention, and fig. 2 is a schematic structural diagram of the integrated apparatus according to an embodiment of the present invention, and as shown in fig. 1 and 2, the integrated apparatus for converting crude oil into petrochemical products comprises: flash tank (including first flash tank 2 and second flash tank 3), pyrolysis furnace 5, catalytic cracking device 4 and piece-rate system 6, wherein the feed end of pyrolysis furnace 5 and the feed end of catalytic cracking device 4 communicate with the discharge end of flash tank respectively, and the discharge end of pyrolysis furnace 5 and the discharge end of catalytic cracking device 4 communicate with the feed end of piece-rate system 6 respectively. The integration method comprises the following steps: the crude oil 11 is subjected to flash separation in a flash tank to obtain a light component 21, a medium component 31 and a heavy component 32, the light component 21 enters a cracking furnace 5 to obtain a thermal cracking product 51, the medium component 31 and the heavy component 32 respectively enter a catalytic cracking device 4 to perform cracking reaction to obtain an oil-gas mixture 43, and the thermal cracking product 51 and the oil-gas mixture 43 are separated in a separation system 6 to obtain gas 60, ethane 61, ethylene 62, propane 63, propylene 64, C4 hydrocarbon 65, light gasoline 66, heavy gasoline 67, diesel oil 68 and slurry oil 69.

The integrated method mainly comprises crude oil flash evaporation, thermal cracking, catalytic cracking and oil-gas separation, and can further comprise a plurality of steps of crude oil electric desalting, gasoline hydrogenation, hydrogenated gasoline separation, aromatic hydrocarbon extraction, reforming, diesel oil hydrogenation and the like.

Crude oil 11 treated in accordance with the present invention is from a crude oil storage tank or oil pipeline and includes one or more of paraffinic, intermediate based and naphthenic crude oils, preferably paraffinic crude oils.

Before the crude oil 11 is subjected to flash separation, the crude oil can be subjected to electric desalting treatment by using the electric desalting device 1 to obtain the desalted crude oil 12, the electric desalting device 1 can be a desalting tank which is arranged in front of the flash tank, and the discharge end is communicated with the feed end of the flash tank. In order to reach the temperature required for desalting, the crude oil 11 may be preheated to 80-200 ℃ before it is introduced into the desalting tank 1. In order to achieve a better desalting effect, the temperature in the desalting tank 1 is 80-200 ℃, preferably 100-150 ℃, the pressure is 0.1-0.5 MPa, preferably 0.1-0.3 MPa, the water injection amount is 1-10 wt%, preferably 3-8 wt%, and the electric field intensity is 200-1000V/cm, preferably 400-800V/cm.

Take off back crude oil 12 and introduce the flash tank after preheating and carry out flash separation, the flash tank includes first flash tank 2 and second flash tank 3, can carry out twice flash processing to taking off back crude oil 12, include: firstly, the first flash processing is carried out on the de-oiled crude oil 12 in a first flash tank 2, a light component 21 is led out from the top of the first crude oil flash tank 2, a medium heavy component 22 is led out from the bottom of the first crude oil flash tank 2, then the second flash processing is carried out on the medium heavy component 22 in a second flash tank 3, a medium component 31 is led out from the top of the second crude oil flash tank 3, and a heavy component 32 is led out from the bottom of the second crude oil flash tank 3, so that the de-oiled crude oil 12 is separated into the light component 21, the medium component 31 and the heavy component 32.

In order to reach the temperature required for the first flash treatment, the de-watered crude oil 12 may be cooled to 50-80 ℃ before it is introduced into the first flash tank 2. The temperature of the first flash evaporation treatment is 50-80 ℃, preferably 50-65 ℃, the pressure is 0.1-0.3 MPa, preferably 0.12-0.2 MPa, and the cutting point of the light component 21 and the medium heavy component 22 is 40-60 ℃, preferably 40-50 ℃.

To achieve the temperature required for the second flash treatment, the medium heavy components 22 may be preheated to 200-300 ℃ before being introduced into the second flash tank 3. The temperature of the second flash evaporation treatment is 200-300 ℃, preferably 220-250 ℃, the pressure is 0.1-0.3 MPa, preferably 0.12-0.2 MPa, and the cutting point of the medium component 31 and the heavy component 32 is 210-240 ℃, preferably 220-230 ℃.

Two discharge ends of the first flash tank 2 are respectively communicated with a feed end of the cracking furnace 5 and a feed end of the second flash tank 3, so that the light components 21 are fed into the cracking furnace 5, and the medium heavy components 22 are fed into the second flash tank 3. Two discharge ends of the second flash tank 3 are respectively communicated with different reaction areas in the catalytic cracking device 4, so that the medium component 31 and the heavy component 32 are respectively sent into different reactors in the catalytic cracking device 4.

In the cracking furnace 5, the light component 21 undergoes a thermal cracking reaction at a reaction temperature of 750 to 900 ℃, preferably 780 to 880 ℃, a reaction pressure of 0 to 175kPa (gauge pressure), preferably 50 to 150kPa (gauge pressure), and a residence time of 0.05 to 1 second, preferably 0.1 to 0.5 second, and the obtained thermal cracking product 51 is introduced into the oil-gas separation system 6 for separation.

The catalytic cracking device 4 comprises a first fluidized bed reactor 4-1, a first riser reactor 4-2, a second fluidized bed reactor 4-4, a stripper 4-5, a settler 4-6 and a regenerator 4-7, wherein the first fluidized bed reactor 4-1 and the first riser reactor 4-2 are respectively communicated with the second fluidized bed reactor 4-4, the stripper 4-5 is positioned below the second fluidized bed reactor 4-4, the settler 4-6 is positioned above the second fluidized bed reactor 4-4, and the regenerator 4-7 is respectively communicated with the first fluidized bed reactor 4-1, the first riser reactor 4-2 and the stripper 4-5 to provide regenerated catalyst and recover the spent catalyst.

The feeding end of the first fluidized bed reactor 4-1 is communicated with one discharging end of the second flash tank 3, and the medium component 31 is taken as the feeding material 41 of the first fluidized bed reactor and is introduced into the first fluidized bed reactor 4-1 of the catalytic cracking device 4 to contact and react with the cracking catalyst (from the regenerator 4-7). The reacted oil mixture is separated by a separating device, the separated first fluidized bed reactor discharge 42 is introduced into a second fluidized bed reactor 4-4, and the spent catalyst is introduced into a first riser reactor 4-2, so that the property of the catalyst in the first riser reactor 4-2 can be adjusted. The first fluidized bed reactor 4-1 is selected from the group consisting of a fixed fluidized bed reactor, a bulk fluidized bed reactor, a bubbling bed reactor, a turbulent bed reactor, a fast bed reactor, a transport bed reactor, and a dense phase fluidized bed reactorOne or more of the reactors, the reaction temperature is 580-720 ℃, the preferable temperature is 620-670 ℃, and the weight hourly space velocity is 1-30 hours^-1Preferably 3 to 10 hours^-1The pressure in the reactor is 0.1 to 0.4MPa (absolute pressure), preferably 0.15 to 0.3 MPa.

The feeding end of the first riser reactor 4-2 is communicated with the other discharging end of the second flash tank 3, so that the heavy raw material 32 is introduced into the first riser reactor 4-2 for catalytic cracking, is in contact reaction with the regenerated catalyst from the regenerator 4-7 and the spent catalyst from the first fluidized bed reactor 4-1, and the oil mixture after the reaction is introduced into the second fluidized bed reactor 4-4 for continuous reaction; the first riser reactor 4-2 is selected from one or more of an equal-diameter riser reactor, an equal-linear-speed riser reactor and a variable-diameter riser reactor, the reaction temperature is 480-620 ℃, the reaction temperature is preferably 520-600 ℃, the agent-oil ratio is 2-25, the reaction time is preferably 3-20, and the reaction time is 1-15 seconds, preferably 2-10 seconds.

The catalytic cracking unit 4 may further include a second riser reactor 4-3, the second riser reactor 4-3 is communicated with the second fluidized bed reactor 4-4, and a feeding end of the second riser reactor 4-3 is communicated with a discharging end of the separation system 6, for receiving the C4 hydrocarbon 65 and the light gasoline 66 separated by the separation system 6. C4 hydrocarbon 65 and light gasoline 66 contact with the regenerated catalyst from the regenerator 4-7 in the second riser reactor 4-3 for reaction, and the oil mixture after the reaction is introduced into the second fluidized bed reactor 4-4 for continuous reaction; the second riser reactor is selected from one or more of an equal-diameter riser reactor, an equal-linear-speed riser reactor and a variable-diameter riser reactor, the reaction temperature is 560-720 ℃, the preferable temperature is 580-680 ℃, the agent-oil ratio is 3-40, the preferable time is 5-30, and the reaction time is 0.5-10 seconds, and the preferable time is 1-5 seconds.

The reaction oil gas from the first fluidized bed reactor 4-1, the oil mixture from the first riser reactor 4-2 and the oil mixture from the second riser reactor 4-3 can be introduced into the second fluidized bed reactor 4-4 together for continuous reaction, the reacted oil mixture is separated by a separating device in a settler 4-6, and the oil-gas mixture 43 is introduced into an oil-gas separating system 6 for reactionAnd (3) separating, namely, after the catalyst to be regenerated is stripped by a stripper 4-5, introducing the catalyst to be regenerated into a regenerator 4-7 for regeneration, and introducing the regenerated catalyst into the first fluidized bed reactor 4-1, the first riser reactor 4-2 and the second riser reactor 4-3 for recycling. The second fluidized bed reactor is one or more selected from a fixed fluidized bed reactor, a bulk fluidized bed reactor, a bubbling bed reactor, a turbulent bed reactor, a fast bed reactor, a conveying bed reactor and a dense-phase fluidized bed reactor, the reaction temperature is 520-700 ℃, the preferable temperature is 580-650 ℃, and the weight hourly space velocity is 1-30 hours^-1Preferably 5 to 20 hours^-1The pressure in the reactor is 0.1 to 0.4MPa (absolute pressure), preferably 0.15 to 0.3 MPa.

The separation device in the catalytic cracking device 4 is preferably a quick separation device for quickly separating reaction oil gas from the carbon deposit catalyst, and the oil gas and the carbon deposit catalyst after reaction are quickly separated by the quick separation device, so that the yield of dry gas can be reduced, and the propylene is inhibited from being converted after being generated.

The cracking catalyst can be regenerated in the regenerator 4-7 by introducing regeneration air 44 into the regenerator 4-7 and discharging regeneration flue gas 45, thereby recycling the catalyst.

The cracking catalyst loaded in the catalytic cracking device 4 contains cracking active components, a contact agent, clay and a binder, wherein the content of the cracking active components is 20-70 wt%, preferably 30-50 wt% based on the dry weight of the cracking catalyst; the content of the clay is 15-60 wt%, preferably 30-50 wt%; the content of the binder is 20-35 wt%, preferably 20-30 wt%.

The cracking active component in the cracking catalyst comprises a molecular sieve with an MFI structure, an optional Y molecular sieve and an optional beta molecular sieve, wherein the content of the Y molecular sieve is 0-90 wt%, preferably 50-80 wt%, the content of the molecular sieve with the MFI structure is 1-50 wt%, preferably 10-40 wt%, and the content of the beta molecular sieve is 0-50 wt%, preferably 10-40 wt%, based on the total weight of the cracking active component.

The molecular sieve having the MFI structure is selected from one or more of ZRP zeolite, phosphorus-containing ZRP zeolite (CN1194181A), rare earth-containing ZRP zeolite (CN1052290A), phosphorus-and rare earth-containing ZRP zeolite (CN1147420A), phosphorus-and alkaline earth metal-containing ZRP zeolite (CN1211470A), and phosphorus-and transition metal-containing ZRP zeolite (CN1465527A), preferably phosphorus-and rare earth-containing ZRP zeolite.

The Y molecular sieve is selected from one or more of HY, USY, REUSY, REY, REHY, DASY and REDASY, or Y type molecular sieve obtained by treating with various metal oxides.

The beta molecular sieve is a beta molecular sieve modified by phosphorus and a transition metal M, wherein M is selected from one or more of Fe, Co, Ni, Cu, Mn, Zn and Sn. The beta molecular sieve modified by phosphorus and transition metal M can be prepared by various methods, for example, phosphorus and transition metal M can be introduced in the process of synthesizing the beta molecular sieve, or the phosphorus and transition metal M can be introduced by adopting the steps of ammonium exchange, phosphorus modification, transition metal M modification, baking treatment and the like after the beta molecular sieve is synthesized. Specific preparation of beta molecular sieves can be found in CN1035668C and CN 1041616C.

In the cracking catalyst, the clay is selected from one or more of various clays which can be used as a catalyst component, such as kaolin, montmorillonite and bentonite; the binder is selected from one or more of silica sol, aluminum sol and pseudo-boehmite, and the preferred binder is double-aluminum binder of the aluminum sol and the pseudo-boehmite.

Separating the thermal cracking product 51 and the oil-gas mixture 43 in a separation system 6 to obtain gas 60, ethane 61, ethylene 62, propane 63, propylene 64, C4 hydrocarbon 65, light gasoline 66, heavy gasoline 67, diesel oil 68 and oil slurry 69, wherein the gas 60 is gas hydrocarbon after removing ethylene, propylene, ethane, propane and C4 hydrocarbon, mainly hydrogen and methane; c4 hydrocarbons 65 include C4 alkanes and C4 alkenes; the light gasoline 66 is light gasoline rich in olefin, the olefin content of the light gasoline is 20-95 wt%, preferably 35-90 wt%, and preferably more than 50 wt%, the boiling range is 30-100 ℃, and preferably 40-90 ℃; the heavy gasoline 67 is preferably heavy gasoline rich in aromatic hydrocarbon, and the aromatic hydrocarbon content is 30-90 wt%, preferably 40-80 wt%, and most preferably more than 50 wt%; the boiling range is 90-200 ℃, and preferably 100-180 ℃. The diesel oil 68 is a fraction having a boiling range of 180 to 350 ℃ obtained by distillation, preferably a fraction having a boiling range of 200 to 340 ℃. Slurry 69 represents a fraction obtained by distillation having a boiling range above 340 c, preferably above 350 c.

The gas 60 can be used as fuel to provide process heat, the ethylene 61 and propylene 63 are directly collected as products, the ethane 62 and propane 64 can be led back to the cracking furnace 5 for reaction, the C4 hydrocarbon and the light gasoline 66 are led into the second riser reactor 4-3 for reaction, the heavy gasoline 67 is led into the gasoline hydrogenation device 7 for hydrogenation treatment, the diesel 68 is led into the diesel hydrogenation device 11 for treatment, and the slurry oil 69 is directly discharged from the device.

The liquid product treatment units 7-11 in fig. 1 mainly treat heavy gasoline 67 and diesel oil 68, and include a gasoline hydrogenation device 7, a hydrogenated gasoline separation device 8, an extraction device 9, a reforming device 10 and a diesel oil hydrogenation device 11.

The feed end of the gasoline hydrogenation device 7 is communicated with the discharge end of the separation system 6 and is used for receiving and processing the heavy gasoline 67 separated by the separation system 6 to obtain hydrogenated gasoline 71. The reaction conditions of gasoline hydrotreatment are as follows: the reaction temperature is 200-350 ℃, and the volume space velocity is 1-5 hours^-1The volume ratio of hydrogen to oil is 100-400 Nm³/m³。

The feed end of the hydrogenated gasoline separation device 8 is communicated with the discharge end of the gasoline hydrogenation device 7, and hydrogenated gasoline 71 is separated to obtain C6-C8 hydrocarbon 82, C9 and above hydrocarbon 83 and C5 hydrocarbon 84.

The feed end of the extraction device 9 is communicated with the discharge end of the hydrogenated gasoline separation device 8, and C6-C8 hydrocarbon 82 is subjected to extraction treatment in the extraction device 9 to obtain raffinate oil 91 and light aromatic hydrocarbons 92. The extraction principle is as follows: the C6-C8 hydrocarbon and the solvent are in countercurrent contact in the extraction tower, the solvent can selectively dissolve aromatic hydrocarbon and non-aromatic hydrocarbon, the aromatic hydrocarbon component is dissolved in the solvent, the non-aromatic hydrocarbon component is less dissolved, two phases with different compositions and different densities are formed, then countercurrent contact and gradual separation are carried out in the tower, the rich solvent rich in the aromatic hydrocarbon obtained at the bottom of the tower is subjected to extractive distillation and reduced pressure stripping, so that the mixed aromatic hydrocarbon is separated from the solvent, and the pure mixed aromatic hydrocarbon is obtained.

The extraction device 9 can be an extraction tower, the solvent for extraction treatment is one or more of sulfolane, N-methylpyrrolidone, dimethyl sulfoxide and formylmorpholine, sulfolane is preferred, the content of water in the solvent is 0.5-2 wt%, 0.7-1.2 wt% is preferred, and the mass ratio of the solvent to C6-C8 hydrocarbon is 2-5, and 3-4 is preferred; the temperature of the top of the extraction tower is 80-100 ℃, preferably 85-95 ℃, the temperature of the bottom of the extraction tower is 170-190 ℃, preferably 175-185 ℃, and the pressure is 0.2-0.6 MPa, preferably 0.4-0.55 MPa.

The feed end of the reforming device 10 is communicated with the discharge end 9 of the extraction device, the raffinate oil 91 can be introduced into the reforming device 10 for reforming, and the reaction conditions of reforming are as follows: the reaction temperature is 450-550 ℃ and the volume space velocity is 1-10 hours^-1The volume ratio of hydrogen to oil is 1-10 Nm³/m³And the reaction pressure is 0.2-1.0 MPa. The reformate 101 may be reintroduced into the hydrogasoline separation unit 8 as the hydrogasoline separation feed 10 for separation.

The feed end of the diesel hydrogenation device 11 is communicated with the discharge end of the separation system 6 and one discharge end of the hydrogenated gasoline separation device 8, and the diesel oil 68 separated by the separation system 6 and the hydrocarbon 83 of more than C9 separated by the hydrogenated gasoline separation device 8 can be used as the diesel hydrogenation feed 111 to carry out diesel hydrogenation in the diesel hydrogenation device 11, so as to obtain the hydrogenated diesel oil 112. The reaction conditions of diesel oil hydrogenation are as follows: the reaction temperature is 330-450 ℃, and the volume space velocity is 0.1-2.0 hours^-1Hydrogen-oil volume ratio of 1000-2000 Nm³/m³。

The discharge end of the diesel hydrogenation unit 11 and the other discharge end of the hydrogenated gasoline separation unit 8 are respectively communicated with the feed end of the catalytic cracking unit 4, so that hydrogenated diesel 112 and C5 hydrocarbons 84 can be introduced into the first fluidized bed reactor 4-2 of the catalytic cracking unit 4 to react with the heavy components 32.

In the integration method and the integration device, crude oil is separated in a flash tank, the separated light components are introduced into a thermal cracking reactor for cracking reaction, the medium components are introduced into a first fluidized bed reactor for catalytic cracking, and the heavy components are introduced into a first riser reactor for catalytic cracking reaction. Because the crude oil atmospheric tower and the vacuum tower are not arranged, the energy consumption can be greatly saved, and meanwhile, the catalytic cracking device adopts a combined reactor type combining double lifting pipes and a fluidized bed, so that the different reaction zones can be accurately controlled in a subarea mode, and the yield of low-carbon olefin and light aromatic hydrocarbon is improved.

The present invention will be described in detail with reference to examples, but the scope of the present invention is not limited thereto.

Examples

In the embodiment and the comparative example of the invention, the gas product is tested by adopting a petrochemical analysis method RIPP 77-90 method, the composition of the organic liquid product is determined by adopting an SH/T0558-1993 method, and the light aromatic hydrocarbon in the gasoline is determined by adopting a petrochemical analysis method RIPP 82-90.

Example 1

Crude oil electric desalting, crude oil flash evaporation, catalytic cracking, thermal cracking, gasoline hydrogenation, diesel hydrogenation and reforming tests are carried out on a medium-sized test device, and material compositions of an oil-gas separation system, a hydrogenated gasoline separation system and an aromatic hydrocarbon extraction system are obtained through flow modeling in Aspen Plus.

Preheating the crude oil A to 130 ℃, introducing the crude oil A into an electric desalting device for desalting treatment, wherein the electric desalting tank is a primary desalting tank, the temperature of the desalting tank is 130 ℃, the pressure of the desalting tank is 0.2MPa, the water injection amount is 5 wt%, and the electric field intensity is 600V/cm.

Cooling the removed crude oil to 60 ℃, introducing the crude oil into a first crude oil flash tank for separation, wherein the temperature of the flash tank is 60 ℃, and the pressure is 0.12 MPa. Light components are led out from the top of the first crude oil flash tank and are led into a cracking furnace for thermal cracking reaction, and the conditions of the cracking furnace in the thermal cracking process are as follows: the outlet temperature of the coil pipe is 850 ℃, the steam/oil ratio is 0.4, the reaction pressure is 100kPa, the residence time is 0.3 s, and the obtained oil-gas product is introduced into an oil-gas separation system.

The components led out from the bottom of the first crude oil flash tank are preheated to 230 ℃ and then led into a second crude oil flash tank for separation, wherein the temperature of the flash tank is 230 ℃, and the pressure is 0.12 MPa. The middle-quality components led out from the top of the second crude oil flash tank are led into a first fluidized bed reactor of the catalytic cracking device, the heavy-quality components led out from the bottom are led into a first riser reactor of the catalytic cracking device, the C4 hydrocarbon and the light gasoline obtained from the separation system are led into a second riser reactor of the catalytic cracking device and are respectively in contact reaction with the regenerated catalyst from the regenerator,introducing the reacted oil mixture into a second fluidized bed reactor for continuous reaction, separating the reacted oil mixture by a separating device, recycling the regenerated carbon-deposited catalyst, and introducing the reacted oil gas into an oil-gas separation tower. The reaction temperature of the first riser reactor is 580 ℃, the agent-oil ratio is 10, and the reaction time is 3 seconds; the reaction temperature of the second riser reactor is 620 ℃, the agent-oil ratio is 10, and the reaction time is 2 seconds; the reaction temperature of the first fluidized bed reactor is 650 ℃, and the weight hourly space velocity is 8 hours^-1The pressure in the reactor was 0.2MPa (absolute pressure); the reaction temperature of the second fluidized bed reactor is 580 ℃, and the weight hourly space velocity is 4 hours^-1The pressure in the reactor was 0.2MPa (absolute pressure).

Introducing the product of the catalytic cracking device into an oil-gas separation system for separation to respectively obtain gas, ethane, ethylene, propane, propylene, C4 hydrocarbon, light gasoline, heavy gasoline, diesel oil and slurry oil.

Wherein the heavy gasoline is introduced into a gasoline hydrogenation device for treatment, the reaction temperature of gasoline hydrogenation is 320 ℃, and the volume space velocity is 3 hours^-1Hydrogen-oil volume ratio 300Nm³/m³。

The hydrogenated gasoline is separated to obtain C5 hydrocarbon, C6-C8 hydrocarbon and hydrocarbon above C9. Wherein C6-C8 hydrocarbon is introduced into an aromatic extraction device for extraction, and the conditions of the aromatic extraction device are as follows: the temperature at the top of the column was 85 ℃, the temperature at the bottom of the column was 185 ℃, the pressure was 0.5MPa, the mass ratio of the solvent to the heavy naphtha was 3.5, and the water content in the solvent was 0.8 wt%.

Introducing the obtained raffinate oil into a reforming device for reaction, wherein the reaction temperature of the reforming device is 480 ℃, and the volume space velocity is 8 hours^-1Hydrogen/oil volume ratio of 5Nm³/m³And the reaction pressure is 0.4 MPa.

The diesel oil obtained by the oil-gas separation system is introduced into a diesel oil hydrogenation device for treatment, the reaction temperature of the diesel oil hydrogenation is 385 ℃, and the volume space velocity is 0.8 hour^-1Hydrogen/oil volume ratio 1500Nm³/m³. The obtained hydrogenated diesel oil is introduced into a second riser reactor of the catalytic cracking device.

The reaction results are shown in Table 1.

Example 2

The process of example 1 was followed except that ethane and propane obtained from the oil-gas separation system were introduced into the cracking furnace to conduct the cracking reaction. The reaction results are shown in Table 1.

Example 3

The process of example 1 was followed except that the C5 hydrocarbons obtained in the hydrogenated gasoline separation system were introduced into the first fluidized bed reactor of the catalytic cracking unit to react. The reaction results are shown in Table 1.

Example 4

The method of example 1 was followed except that ethane and propane obtained from the oil-gas separation system were introduced into the cracking furnace for cracking reaction, and C5 hydrocarbons obtained from the hydrogenated gasoline separation system were introduced into the first fluidized bed reactor of the catalytic cracking unit for reaction. The reaction results are shown in Table 1.

Comparative example 1

Crude oil electric desalting, catalytic cracking and thermal cracking tests are carried out on a medium-sized test device, and the material compositions of crude oil atmospheric distillation, an oil-gas separation system and aromatic hydrocarbon extraction are obtained by flow modeling in Aspen Plus.

Preheating the crude oil A to 120 ℃, introducing the crude oil A into an electric desalting device for desalting treatment, wherein the electric desalting tank is a primary desalting tank, the temperature of the desalting tank is 120 ℃, the pressure of the desalting tank is 0.2MPa, the water injection amount is 5 weight percent, and the electric field intensity is 600V/cm.

And introducing the removed crude oil into a normal pressure fractionating tower for separation to obtain fuel gas, gasoline, diesel oil and tower bottom oil. Introducing tower bottom oil into a riser reactor of a catalytic cracking device, carrying out contact reaction with a regenerated catalyst from a regenerator, introducing an oil agent mixture after reaction into a fluidized bed reactor for continuous reaction, separating the oil agent mixture after reaction through a separating device, recycling the carbon-deposited catalyst after regeneration, and introducing the reaction oil gas into an oil-gas separation tower. The reaction temperature of the riser reactor is 580 ℃, the agent-oil ratio is 10, and the reaction time is 4 seconds; the reaction temperature of the fluidized bed reactor is 560 ℃, and the weight hourly space velocity is 8 hours^-1The pressure in the reactor was 0.2 MPa.

The ethane and propane obtained by the oil-gas separation system are introduced into a cracking furnace for cracking reaction, and the conditions of the cracking furnace in the thermal cracking process are as follows: the outlet temperature of the coil pipe is 845 ℃, the steam/oil ratio is 0.3, the reaction pressure is 100kPa, the residence time is 0.3 seconds, and the obtained oil-gas product is introduced into an oil-gas separation system.

Heavy gasoline is introduced into a gasoline hydrogenation device for treatment, the reaction temperature of gasoline hydrogenation is 330 ℃, and the volume space velocity is 4 hours^-1Hydrogen-oil volume ratio of 350Nm³/m³。

The hydrogenated gasoline is separated to obtain C5 hydrocarbon, C6-C8 hydrocarbon and hydrocarbon above C9. Wherein C6-C8 hydrocarbon is introduced into an aromatic extraction device for extraction, and the conditions of the aromatic extraction device are as follows: the temperature at the top of the column was 80 ℃, the temperature at the bottom of the column was 180 ℃, the pressure was 0.4MPa, the mass ratio of the solvent to the heavy naphtha was 3.8, and the water content in the solvent was 0.8 wt%. The reaction results are shown in Table 2.

Comparative example 2

The method of comparative example 1 is followed, except that C4 hydrocarbon and light gasoline obtained from the gas separation system are introduced into the second riser reactor of the catalytic cracking unit to contact and react with the regenerated catalyst from the regenerator, the reacted oil mixture is introduced into the fluidized bed reactor connected in series with the outlet of the first riser reactor to continue to react, the reacted oil mixture is separated by the separation unit, the carbon-deposited catalyst is recycled after being regenerated, and the reacted oil gas is introduced into the oil-gas separation system. The reaction temperature of the second riser reactor is 670 ℃, the agent-oil ratio is 10, and the reaction time is 2 seconds; the reaction temperature of the fluidized bed reactor is 620 ℃, and the weight hourly space velocity is 10 hours^-1The pressure in the reactor was 0.2 MPa. The reaction results are shown in Table 2.

Comparative example 3

According to the method of the comparative example 1, except that a diesel hydrogenation device is additionally arranged, the diesel obtained by the oil-gas separation system is introduced into the diesel hydrogenation device for treatment, and the produced hydrogenated diesel is introduced into the first riser reactor of the catalytic cracking device for reaction. The reaction temperature of diesel oil hydrogenation is 380 ℃, and the volume space velocity is 0.85 h^-1Hydrogen-containing oilThe product ratio is 1400Nm3/m 3. The reaction results are shown in Table 2.

Comparative example 4

According to the method of the comparative example 1, except that a reforming device is additionally arranged, raffinate oil obtained by extracting aromatic hydrocarbon is introduced into the reforming device for reaction, and a product after the reaction is introduced into a hydrogenated gasoline separation system for separation. The reaction temperature of reforming is 485 ℃, and the volume space velocity is 8 hours^-1The hydrogen-oil volume ratio was 6Nm3/m3, and the reaction pressure was 0.4 MPa. The reaction results are shown in Table 2.

Table 1 results of the reactions of examples 1 to 4

Table 2 reaction results of comparative examples 1 to 4

As can be seen from tables 1 and 2, compared with the comparative example, the integrated method and the integrated apparatus provided by the present invention can obtain higher yields of low carbon olefins such as ethylene and propylene and light aromatics such as benzene, toluene, xylene, and ethylbenzene.

It should be noted by those skilled in the art that the described embodiments of the present invention are merely exemplary and that various other substitutions, alterations, and modifications may be made within the scope of the present invention. Accordingly, the present invention is not limited to the above-described embodiments, but is only limited by the claims.

Claims

1. An integrated process for converting crude oil to petrochemical products, comprising:

2. The integrated process of claim 1, wherein the catalytic cracking unit comprises a first riser reactor, a first fluidized bed reactor, and a second fluidized bed reactor, wherein the reaction of the medium components and the heavy components in the catalytic cracking unit comprises:

introducing the medium component into the first fluidized bed reactor and contacting with the cracking catalyst for reaction to obtain a first oil agent mixture;

introducing the heavy component into the first riser reactor and contacting with the cracking catalyst for reaction to obtain a second oil agent mixture;

and introducing the first oil mixture and the second oil mixture into the second fluidized bed reactor for reaction, and separating to obtain the oil-gas mixture.

3. The integrated process of claim 2, wherein the reaction conditions of the first fluidized bed reactor are: the reaction temperature is 580-720 ℃, the preferable temperature is 620-670 ℃, and the weight hourly space velocity is 1-30 hours^-1Preferably 3 to 10 hours^-1The pressure in the reactor is 0.1-0.4 MPa, preferably 0.15-0.3 MPa; the reaction temperature of the first riser reactor is 480-620 ℃, the preferable temperature is 520-600 ℃, the agent-oil ratio is 2-25, the preferable temperature is 3-20, and the reaction time is 1-15 seconds, the preferable time is 2-10 seconds; the reaction temperature of the second fluidized bed reactor is 520-700 ℃, preferably 580-650 ℃, and the weight hourly space velocity is 1-30 hours^-1Preferably 5 to 20 hours^-1The pressure in the reactor is 0.1 to 0.4MPa, preferably 0.15 to 0.3 MPa.

4. The integrated process of claim 2, wherein the cracking catalyst comprises a cracking active component, a clay and a binder, the cracking active component comprises a molecular sieve with MFI structure, the clay is selected from one or more of kaolin, montmorillonite and bentonite, the binder is selected from one or more of silica sol, alumina sol and pseudo-boehmite, and the content of the cracking active component is 20-70 wt%, preferably 30-50 wt% based on the dry weight of the cracking catalyst; the content of the clay is 15-60 wt%, preferably 30-50 wt%; the content of the binder is 20-35 wt%, preferably 20-30 wt%.

5. The integrated process of claim 4, wherein the cracking active component comprises an optional Y molecular sieve and an optional beta molecular sieve, wherein the content of the Y molecular sieve is 0-90 wt%, preferably 50-80 wt%, the content of the molecular sieve with MFI structure is 1-50 wt%, preferably 10-40 wt%, and the content of the beta molecular sieve is 0-50 wt%, preferably 10-40 wt%, based on the total weight of the cracking active component.

6. The integrated process of claim 1, further comprising introducing ethane and propane separated by the separation system into the cracking furnace, wherein the reaction temperature of the thermal cracking is 750-900 ℃, preferably 780-880 ℃, the reaction pressure is 0-175 kPa, preferably 50-150 kPa, and the residence time is 0.05-1 second, preferably 0.1-0.5 second.

7. The integrated process of claim 2, further comprising introducing the heavy gasoline separated by the separation system into a gasoline hydrotreater for hydrotreating to obtain hydrogenated gasoline, wherein the reaction conditions of the hydrotreating are as follows: the reaction temperature is 200-350 ℃, and the volume space velocity is 1-5 hours^-1The volume ratio of hydrogen to oil is 100-400 Nm³/m³。

8. The integrated process of claim 7, further comprising separating the hydrogenated gasoline to obtain C6-C8 hydrocarbons, extracting the C6-C8 hydrocarbons to obtain raffinate oil and light aromatic hydrocarbons, and introducing the raffinate oil into a reforming device for reforming, wherein the extraction treatment is performed in an extraction tower, the extraction treatment is performed with one or more of sulfolane, N-methylpyrrolidone, dimethyl sulfoxide and formylmorpholine, preferably sulfolane, the content of water in the solvent is 0.5-2 wt%, preferably 0.7-1.2 wt%, and the mass ratio of the solvent to the C6-C8 hydrocarbons is 2-5, preferably 3-4; the temperature of the top of the extraction tower is 80-100 ℃, preferably 85-95 ℃, the temperature of the bottom of the extraction tower is 170-190 ℃, preferably 175-185 ℃, the pressure is 0.2-0.6 MPa, preferably 0.4-0.55 MPa, and the reaction conditions of reforming are as follows: the reaction temperature is 450-550 ℃ and the volume space velocity is 1-10 hours^-1The volume ratio of hydrogen to oil is 1-10 Nm³/m³And the reaction pressure is 0.2-1.0 MPa.

9. The integrated process of claim 7 further comprising separating the hydrogenated gasoline to obtain C5 hydrocarbons and C9 or greater hydrocarbons, introducing the C9 or greater hydrocarbons and the diesel separated by the separation system into a diesel hydrotreater for hydrotreating to obtain hydrogenated diesel, and introducing the hydrogenated diesel and the C5 hydrocarbons into the first fluidized bed reactor.

10. The integrated method of claim 7, wherein the catalytic cracking apparatus comprises a second riser reactor, the integrated method further comprises separating the hydrogenated gasoline to obtain C4 hydrocarbons, introducing the C4 hydrocarbons and the light gasoline separated by the separation system into the second riser reactor to contact with the cracking catalyst for reaction, and introducing the reacted oil mixture into the second fluidized bed reactor, wherein the reaction temperature of the second riser reactor is 560-720 ℃, preferably 580-680 ℃, the agent-oil ratio is 3-40, preferably 5-30, and the reaction time is 0.5-10 seconds, preferably 1-5 seconds.

11. The integrated process of any one of claims 1 to 10, wherein the flash separation comprises subjecting the crude oil to a first flash treatment resulting in the light and medium heavy components; and

carrying out second flash evaporation treatment on the medium heavy component to obtain the medium component and the heavy component,

wherein the temperature of the first flash evaporation treatment is 50-80 ℃, preferably 50-65 ℃, the pressure is 0.1-0.3 MPa, preferably 0.12-0.2 MPa, and the cutting point of the light component and the medium heavy component is 40-60 ℃, preferably 40-50 ℃; the temperature of the second flash evaporation treatment is 200-300 ℃, preferably 220-250 ℃, the pressure is 0.1-0.3 MPa, preferably 0.12-0.2 MPa, and the cutting point of the medium component and the heavy component is 210-240 ℃, preferably 220-230 ℃.

12. The integrated process according to any one of claims 1 to 10, further comprising subjecting the crude oil to an electro-desalting treatment at a temperature of 80 to 200 ℃, preferably 100 to 150 ℃, under a pressure of 0.1 to 0.5MPa, preferably 0.1 to 0.3MPa, with a water injection rate of 1 to 10 wt%, preferably 3 to 8 wt%, and with an electric field strength of 200 to 1000V/cm, preferably 400 to 800V/cm, before the flash separation of the crude oil.

13. An integrated apparatus for converting crude oil into petrochemical products, comprising:

a flash tank;

a cracking furnace;

a catalytic cracking unit; and

the separation system is used for separating the liquid from the liquid,

14. The integrated apparatus of claim 13, wherein the catalytic cracking apparatus comprises a first riser reactor, a first fluidized bed reactor and a second fluidized bed reactor, the first riser reactor and the first fluidized bed reactor are respectively communicated with the second fluidized bed reactor, and a discharge end of the second fluidized bed reactor is communicated with a feed end of the separation system.

15. The integrated apparatus of claim 14, wherein the catalytic cracking apparatus further comprises a second riser reactor, the second riser reactor is in communication with the second fluidized bed reactor, and a feed end of the second riser reactor is in communication with a discharge end of the separation system for receiving and processing the C4 hydrocarbons and light gasoline separated by the separation system.

16. The integrated plant of claim 14, wherein the flash tank comprises a first flash tank and a second flash tank, a discharge end of the first flash tank is in communication with a feed end of the cracking furnace and a feed end of the second flash tank, and a feed end of the first riser reactor and a feed end of the first fluidized bed reactor are in communication with a discharge end of the second flash tank, respectively.

17. The integrated apparatus of claim 16, further comprising an electro-desalination apparatus having a discharge end in communication with a feed end of the first flash tank.

18. The integrated device according to any one of claims 13 to 17, further comprising a gasoline hydrogenation device and a hydrogenated gasoline separation device, wherein a feed end of the gasoline hydrogenation device is communicated with a discharge end of the separation system and is configured to receive and process the heavy gasoline separated by the separation system to obtain hydrogenated gasoline, and a feed end of the hydrogenated gasoline separation device is communicated with a discharge end of the gasoline hydrogenation device and is configured to receive and separate the hydrogenated gasoline.

19. The integrated apparatus of any one of claims 13 to 17, further comprising an extraction device and a reforming device, wherein a feed end of the extraction device is communicated with a discharge end of the hydrogenated gasoline separation device and is used for receiving and processing the C6-C8 hydrocarbons separated by the hydrogenated gasoline separation device to obtain raffinate oil and light aromatic hydrocarbons, and a feed end of the reforming device is communicated with a discharge end of the extraction device and is used for receiving and processing the raffinate oil.

20. The integrated apparatus of any one of claims 13 to 17, further comprising a diesel hydrogenation unit, a feed end of the diesel hydrogenation unit being in communication with the discharge end of the separation system and one discharge end of the hydrogenated gasoline separation unit for receiving and processing the diesel separated by the separation system and the hydrocarbons above C9 separated by the hydrogenated gasoline separation unit, and a discharge end of the diesel hydrogenation unit and another discharge end of the hydrogenated gasoline separation unit being in communication with the feed ends of the catalytic cracking units, respectively.