WO2001000751A1

WO2001000751A1 - Catalytic conversion process for reducing olefin, sulfur and nitrogen contents in gasoline

Info

Publication number: WO2001000751A1
Application number: PCT/CN2000/000171
Authority: WO
Inventors: Youhao Xu; Jiushun Zhang; Jun Long; Xieqing Wang; Ruichi Zhang; Yinan Yang; Jianhong Gong
Original assignee: China Petrochemical Corporation; Research Institute Of Petroleum Processing, Sinopec
Priority date: 1999-06-23
Filing date: 2000-06-22
Publication date: 2001-01-04

Abstract

A catalytic conversion process for reducing olefin, sulfur and nitrogen contents in gasoline. The pre-heated gasoline material is contacted with catalyst with the amount of carbon deposition ≤ 2.0 wt% and temperature of below 600 °C. The reaction product is separated and the used catalyst is stripped, regenerated for reuse. By means of the process, the gasoline product has olefine content reduced to below 20 wt%, and sulfur and nitrogen contents reduced remarkably.

Description

Catalytic conversion method for reducing olefin, sulfur and nitrogen content in gasoline

The invention belongs to a catalytic conversion method of petroleum hydrocarbons, in particular to a catalytic conversion method for reducing the content of olefins, sulfur and nitrogen in gasoline. Description of the prior art

In recent years, environmental regulations in various countries in the world have put forward increasingly stringent requirements on the quality of gasoline and diesel, especially the requirements for gasoline, such as olefin content, sulfur content, and benzene content. Therefore, environmental protection requirements have become the main driving force for the further development of various refining technologies, and the more traditional catalytic cracking technology is the first.

The conventional catalytic cracking reaction process mainly includes the following steps: (1) Fresh raw oil is mixed with refining oil after heat exchange, injected from the nozzle at the lower part of the riser reactor, and the high temperature regeneration catalyst from the regenerator in the riser reactor. Upon contact, it vaporizes and reacts. The residence time of the oil and gas in the riser is very short. Generally, it enters the settler after a few seconds. The entrained catalyst is separated by the cyclone separator, and then leaves the reactor to the subsequent fractionation system. (2) The coke-accumulated catalyst, that is, the catalyst to be grown, falls into the stripping section below from the settler; the stripping section is equipped with a multi-layered chevron baffle and superheated steam is passed into the bottom. The oil and gas between the catalyst particles are replaced by water vapor and returned to the settler; the stripped catalyst that is to be produced enters the regenerator through the inclined pipe that is to be produced. (3) The main function of the regenerator is to burn off the coke formed on the catalyst due to the reaction, so as to restore the activity of the catalyst. The regeneration air is supplied by the main fan, and the air enters the catalyst dense phase bed through the distribution plate below the regenerator; the regenerated catalyst, that is, the regenerated catalyst, falls into the overflow pipe and is sent back to the reactor for recycling through the regeneration inclined pipe; The regenerated flue gas is separated from the entrained catalyst by the cyclone, and then part of the energy is recovered by the smoke system and discharged into the atmosphere.

As is known to all, the olefin content of FCC gasoline is 35 to 65% by weight, which is a relatively representative olefin-rich gasoline fraction. Although this gasoline has a high octane number, it has poor thermal stability and tends to form gums; after combustion, it will also increase the amount of active hydrocarbons and polyenes in emissions. In addition, as the FCC feedstock continues to be re-densified and degraded, the sulfur content and nitrogen content in its gasoline products are also increasing; after combustion, emissions will increase by 30 _{) (} and _{) (} , which will cause serious environmental pollution. In addition to FCC gasoline, straight-run gasoline, coking gasoline, and visbreaked gasoline also have similar problems, and should not be directly used as a blending component of commercial gasoline.

Hydrorefining is an effective measure to solve the above problems. Catalytic modification of the oil is achieved through hydrogenation under hydrogen pressure, and the purposes of desulfurization, denitrification, olefin saturation, and aromatic hydrocarbon saturation are achieved. The saturation of olefins and aromatics in gasoline will greatly reduce the octane number of gasoline. USP5, 154, 818 discloses a catalytic cracking method for producing high-octane gasoline using a variety of petroleum hydrocarbons as raw materials. In the method, a riser reactor is divided into a first reaction zone and a second reaction zone from bottom to top; a gasoline fraction is contacted with a candidate catalyst containing a shape-selective molecular sieve or a mesoporous molecular sieve in a first reaction zone, and an aromatic structure occurs; Reaction and oligomerization reaction, the reaction temperature is 371 ~ 538 ° C, and the generated reaction stream enters the second reaction zone along the riser in the form of dilute phase transportation; and the heavy hydrocarbon raw material and the regeneration catalyst react in the second reaction. Conventional catalytic cracking reactions occur in the zone contact; the generated oil and gas are separated in the settler, and the oil and gas are sent to the subsequent separation system. After the gaseous catalyst is stripped, part of it returns to the first reaction zone, and the other part enters the regenerator. Charred regeneration, the hot regenerated catalyst is returned to the second reaction zone for recycling. Object of the invention

The object of the present invention is to provide a new method for gasoline upgrading, in order to catalyze the conversion of olefins in gasoline into isomerized hydrazones and aromatic hydrocarbons, and significantly reduce the sulfur and nitrogen content in gasoline. Brief description of the invention

The inventors have discovered that: olefins in gasoline can be selectively converted into iso-paraffins and aromatic hydrocarbons, or isomerized p-hydrocarbons and coke under a certain reaction environment.

The method provided by the present invention is as follows: the pre-heated gasoline fraction is contacted with a catalyst having a carbon deposition amount of ≤2.0% by weight and a temperature lower than 600 ° C, at 100 ~ 600 ° C, 130 ~ 450Kpa, and the weight hourly space velocity is l ~ 120h- The reaction takes place under the conditions of a weight ratio of catalyst to gasoline fraction of 2 to 20 and a weight ratio of water vapor to gasoline fraction of 0 to 0.3; separation of the reaction product and the regenerant; the regenerant is stripped Recycling after regeneration.

The hydrocarbon feedstock applicable to the present invention is a gasoline fraction. The gasoline fraction may be a full fraction, for example, a fraction at about 40 to 200 ° C; or a narrow fraction thereof, for example, a fraction at 70 to 145 ° C. The gasoline fraction may be a primary processed gasoline fraction, a secondary processed gasoline fraction, or a mixture of one or more of the foregoing gasoline fractions. The gasoline fraction may have an olefin content of 10 to 90% by weight and contain a small amount of impurities such as sulfur and nitrogen. For example, the sulfur content is above ²⁰⁰ ppm and the nitrogen content is above 30 ppm.

The catalyst used in the present invention may be any catalyst suitable for the catalytic cracking process, for example, an amorphous silicon aluminum catalyst or a molecular sieve catalyst, wherein the active component of the molecular sieve catalyst is selected from the Y-type or One or more of HY-type zeolite, super-stable Y-type zeolite with or without rare earth and / or phosphorus, ZSM-5 series zeolite or high-silica zeolite with a five-membered ring structure, beta zeolite, and ferrierite.

In the present invention, the catalyst that reacts with gasoline fractions and has a temperature lower than 600 ° C is selected from one of the following three types of catalysts: ① a regenerated catalyst with an amount of carbon deposits ≤ 0.10% by weight; ② an amount of carbon deposits between 0.10 and 0.90% by weight % Reminder Chemical agent; ③ The catalyst to be produced has a carbon deposition amount of 0.90 to 2.0% by weight. For the above three types of catalysts with different carbon deposits, three different implementation schemes are required. BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a schematic flowchart of Embodiment A and Embodiment F provided by the present invention.

FIG. 2 is a schematic flowchart of Embodiment B provided by the present invention.

FIG. 3 is a schematic flowchart of Embodiment C provided by the present invention.

FIG. 4 is a schematic flowchart of Embodiment D provided by the present invention.

FIG. 5 is a schematic flowchart of Embodiment E provided by the present invention.

FIG. 6 is a schematic flowchart of Embodiment G provided by the present invention.

FIG. 7 is a schematic flowchart of Embodiment H provided by the present invention.

FIG. 8 is a schematic flowchart of Embodiment 1 provided by the present invention.

FIG. 9 is a schematic flowchart of Embodiment J provided by the present invention.

FIG. 10 is a schematic flowchart of Embodiment K provided by the present invention.

FIG. 11 is a schematic flowchart of Embodiment L provided by the present invention.

Fig. 12 is a schematic diagram of a conventional stripping section of Embodiment L provided by the present invention.

FIG. 13 is a schematic diagram of a stripping section with a fluidized bed reactor according to Embodiment L provided by the present invention. Detailed description of the invention

According to the method provided by the present invention, the following three different embodiments need to be used when using catalysts with different carbon deposition amounts.

Option 1: When the catalyst reacting with the gasoline fraction is a regenerated catalyst with a coke deposit amount of ≦ 0.10% by weight and a temperature lower than 600 ° C, the reaction process can be carried out in the catalytic conversion of gasoline with a riser or a fluidized bed It can be implemented separately on the device, or it can be implemented in combination with a riser catalytic cracking device or a fluidized bed catalytic cracking device that processes conventional catalytic cracking raw materials. The gasoline catalytic conversion unit is the same as the conventional catalytic cracking unit, except that the operating conditions are different from the conventional catalytic cracking unit. When the joint implementation is adopted, the gasoline fraction and the conventional catalytic cracking raw materials are reacted in their respective reactors; and the settler, the stripper, and the subsequent separation system may be shared or independent of each other; The regeneration system is shared. The reaction of gasoline fractions is carried out under the following conditions: reaction temperature 100 ~ 600 ° C, reaction pressure 1 30 ~ 450kpa, weight hourly space velocity 1 ~ 120 hours-weight ratio of catalyst to gasoline fraction 2 ~ 15, water The weight ratio of steam to gasoline fraction is 0 ~ 0.1; the preferred reaction conditions are as follows: reaction temperature is 150 ~ 550 ° C, reaction pressure is 250 ~ 400kpa, weight hourly space velocity is 2-1 00 hours—the ratio of catalyst to gasoline fraction 01〜0. 05。 The weight ratio is 3 ~ 10, the weight ratio of water vapor to gasoline fraction is 0. 01 ~ 0. 05.

Scheme two: When the catalyst reacting with the gasoline fraction is a catalyst having a carbon deposition amount of 0.10 to 0.90% by weight, and the temperature is lower than 600 ° C, the reaction process may be carried out with a riser or a fluidized bed. Catalytic conversion of gasoline It can be implemented separately on the device, or it can be implemented in combination with a riser catalytic cracking device or a fluidized bed catalytic cracking device that processes conventional catalytic cracking raw materials. The gasoline catalytic conversion unit is the same as the conventional catalytic cracking unit, except that the operating conditions are different from the conventional catalytic cracking unit. When the combined implementation method is adopted, the gasoline fraction and the conventional catalytic cracking raw materials are reacted in their respective reactors; and the settler, the stripper, and the subsequent separation system may be shared or independent of each other; the catalyst The regeneration system is shared. The reaction of gasoline fractions is performed under the following conditions: reaction temperature 300 ~ 600 ° C, reaction pressure 130 ~ 450Kpa, weight hourly space velocity 1 ~ 120h- weight ratio of catalyst to gasoline fraction 2 ~ 15, water vapor and gasoline The weight ratio of the distillate is 0 ~ 0.1; The preferred reaction conditions are as follows: reaction temperature 350 ~ 550 ° C, reaction pressure 250 ~ 400Kpa, weight hourly space velocity is ~: ^!) ^ ¹ , weight ratio of catalyst to gasoline fraction 01-0. 05。 For 3-10, the weight ratio of water vapor to gasoline fraction is 0. 01-0. 05.

In the above schemes 1 and 2, when the combined implementation is adopted, the catalyst in contact with the gasoline fraction and the catalyst in contact with the conventional catalytic cracking feedstock may be the same or different. When different catalysts are used, the zeolite of the catalyst in contact with the gasoline fraction and the zeolite of the catalyst in contact with the conventional catalytic cracking raw material may be selected from Y-type zeolite, HY-type zeolite, ultra-stable Y-type zeolite, ZSM-5 series zeolite, or One or more mixtures of any one or more of high-silica zeolite and ferrierite with a five-membered ring structure. The zeolite may be rare earth and / or phosphorus-containing, or it may be rare earth and phosphorus-free. In order to facilitate the separation of the above two kinds of catalysts in a catalytic cracking device, they should be prepared as catalysts having different physical properties, for example, different particle diameters, different apparent bulk densities, and the like. The above two different catalysts enter different reactors respectively, and contact and react with gasoline fractions or conventional catalytic cracking raw materials. For example, a catalyst with a larger particle size containing ultra-stable Y-type zeolite contacts and reacts with conventional catalytic cracking raw materials to enhance the cracking capacity of heavy oil and improve the reaction selectivity; while a catalyst with a smaller particle size containing rare-earth Y-type zeolite and gasoline Distillation contact and reaction to increase the hydrogen transfer reaction of gasoline. After the two different catalysts are separated by oil agent, they are stripped and regenerated together. After being separated in the stripper and regenerator according to their physical properties, they are different. The catalyst is sent back to the corresponding reactor, so that the reaction and regeneration process are cyclically performed. Catalysts with different particle sizes are delimited by 30 to 40 microns, and catalysts with different apparent bulk densities are delimited by 0.6 to 0.7 g / cm ³ .

Scheme three: When the catalyst reacting with the gasoline fraction is a ready-to-be-produced catalyst having a carbon deposition amount of 0.90 to 2.0% by weight and a temperature lower than 600 ° C, the reaction process is performed in a stripping section, and The stripping section can be selected from one of the following three types: ① a conventional settler stripping section; ② a stripping section which is integrated with a dense phase bed of a catalyst in a fluidized bed reactor; ③ in catalytic cracking A container capable of performing catalyst stripping in the device. And the gasoline fraction should be injected into the stripping section from 10 to 60% of the height of the catalyst dense phase bed in the stripping section. The preferred gasoline distillate injection position is 15 to 55% of the height of the catalyst dense phase bed in the stripping section. The reaction of gasoline fractions is performed under the following conditions: reaction temperature 400 ~ 550 ° (:, reaction pressure 130 ~ 450Kpa, weight hourly space velocity 1 ~ 50h- weight ratio of catalyst to gasoline fraction 3 ~ 20, water vapor and Gasoline fraction The weight ratio is 0.03 0. 30; The preferred reaction conditions are as follows: reaction temperature 420 ~ 520 ° (:, reaction pressure 250 ~ 400Kpa, weight hourly space velocity 2-4 Oh " ¹ , weight ratio of catalyst to gasoline fraction 05〜0. 30。 For 4 ~: L8, the weight ratio of water vapor to gasoline fraction is 0. 05 ~ 0. 30.

The three embodiments described above are divided according to the amount of carbon deposits of the catalysts that react with the gasoline fraction, and the use of catalysts with different carbon deposits necessarily requires different process flows and operations corresponding to them condition. The following describes these three embodiments in detail.

The catalyst used in Scheme 1 is a regenerated catalyst with a carbon deposit ≤ 0.10% by weight and a temperature lower than 600 ° C. The implementation steps are as follows: The preheated gasoline fraction enters the riser or stream of the gasoline catalytic conversion device. The reactor is in contact with a regenerated catalyst in which the amount of carbon deposits is ≤0.10% by weight and the temperature is lower than 600 ° C. The reaction temperature is 100 to 60 (TC, reaction pressure 130 to 450 kpa, weight hourly space velocity 1 to 120). Hours- ¹ , the weight ratio of catalyst to gasoline distillate is 2 ~ 15, the weight ratio of water vapor to gasoline distillate is 0 to 0.1, the reaction conditions are as follows: The reaction temperature is 150 ~ 55 (TC, 01〜0. 05; reaction product, water vapor and the weight ratio of catalyst to gasoline distillate is 3 ~ 10, the weight ratio of water vapor to gasoline distillate is 0 ~ 01 ~ 0. 05; After the reaction, the carbon-containing catalyst is subjected to gas-solid separation; the reaction products are separated to obtain dry gas, liquefied gas rich in propylene and isobutyrium, and gasoline, diesel and other major products rich in isofluorene and aromatic hydrocarbons; Lifting section The hydrocarbon products adsorbed on the agent are sent to the regenerator and burned in the presence of oxygen-containing gas; the high-temperature regeneration catalyst is cooled by the cooler and returned to the reactor for recycling; the cooling process of the regeneration catalyst is the high-temperature catalyst and the low-temperature The heat exchange process of the medium can be completed in this device or in other devices; the cooler used in this process can be independent or non-independent.

The reaction process between gasoline fraction and regenerated catalyst with carbon deposits ≤ 0.10% by weight and temperature below 600 ° C can be implemented separately on a gasoline catalytic conversion unit or with a riser catalytic cracking unit that processes conventional catalytic cracking raw materials Or the fluidized bed catalytic cracking unit is jointly implemented, that is, the apparatus for processing conventional catalytic cracking raw materials is slightly modified according to the requirements of the present invention, so that the gasoline fraction and the conventional catalytic cracking raw materials are first reacted in respective reactors; and after the reaction, The separation of oil and gas and catalyst, the separation of reaction products, and the stripping process of the carbon-containing catalyst after the reaction can be performed separately for the two reaction streams described above, or the two reaction streams can be combined together to perform the process; The regeneration process is performed in common, that is, a common regeneration system is shared.

Five specific embodiments are listed below to further explain the process described in Scheme 1, but Scheme 1 of the present invention is not limited to any specific embodiments below.

Embodiment A: The idle riser catalytic cracking device is transformed into a gasoline catalytic conversion device. The conventional cracked raw materials can be replaced with gasoline fractions, and a catalyst cooler is added downstream of the regenerator to cool the regenerated catalyst to 100 ~ 60 ( TC is then brought into contact with the gasoline fraction, and the generated reaction stream enters the settler to separate the reaction oil and gas from the catalyst to be generated, and the reaction oil enters the subsequent fractionation system for product separation. Embodiment B: For a catalytic cracking device of a single riser reactor, a new riser reactor needs to be newly built. The newly-built riser reactor shares the original settler, stripper, subsequent separation system and regeneration system with the original riser reactor. The raw material of the newly built reactor is gasoline fraction, which is called a gasoline riser; the raw material of the original reactor is a conventional cracked raw material, and the reactor is called a raw oil riser. Gasoline feedstock and conventional cracked feedstock are reacted in the gasoline riser and raw oil riser, respectively, and the mixture of reacting oil, gas and catalyst enters the settler and subsequent separation system together. The separated crude gasoline can be partially returned as the raw material of the gasoline riser. The stand-by catalyst is regenerated after being stripped. The regenerated catalyst is divided into two parts, one of which is returned to the raw oil riser, and the other is returned to the gasoline riser after the catalyst cooler is cooled.

Embodiment C: For a catalytic cracking device of a single riser reactor, a new fluidized bed reactor with or without a riser needs to be newly built, and the reactor may be provided with or without a stripping section. The newly built reactor shares the regenerator with the existing reactor. The raw material of the newly built reactor is gasoline fraction, which is called a gasoline reactor; the raw material of the original reactor is a conventional cracked raw material, and the reactor is called a raw oil riser reactor. Gasoline fractions and conventional cracked raw materials are reacted in a gasoline reactor and a feed oil riser reactor, respectively; the reaction oil and gas generated from gasoline fractions and the reaction oil and gas generated from conventional cracked materials are mixed into a subsequent separation system, or separately into their respective In the separation system, the separated crude gasoline can be partially returned as the raw material of the gasoline riser. The stand-by catalyst is regenerated after being stripped. The regenerated catalyst is divided into two parts, one of which is returned to the feed oil riser, and the other is returned to the gasoline reactor through the cooler.

Embodiment D: Using the same device type as in Embodiment B, the gasoline fraction is cut into two parts: light gasoline (boiling point range 40 ~ 100 ° C) and heavy gasoline (boiling point range 100 ~ 200 ° C). Light gasoline is converted from gasoline The bottom of the riser is injected, and heavy gasoline is injected from the middle and upper part of the gasoline riser to contact the regenerated catalyst. At the same time, the pre-heated conventional cracking raw materials enter from the bottom of the raw oil riser and come into contact with the high-temperature regenerated catalyst. The above two reactions The reaction streams generated by the reactor are mixed, enter the settler in turn, and the subsequent separation system realizes the separation of the reaction products. The catalyst to be regenerated is stripped and regenerated. The regenerated catalyst is divided into two parts, one of which is returned to the feed oil riser, and the other is After being cooled by the cooler, it returns to the gasoline riser.

Embodiment E: The method provided by the present invention can also be implemented by combining a new type of riser reactor with a conventional catalytic cracking device. The new riser reactor has been disclosed in a patent application with a publication number of CN1237477A and an invention name of "a riser reactor for fluid catalytic conversion". From the bottom to the top in the vertical direction, the reactor is: a pre-lift section that is coaxial with each other, a first reaction zone, a second reaction zone with an enlarged diameter, an exit zone with a reduced diameter, and a horizontal section at the end of the exit zone. tube. The bonding site of the first and second reaction zones is a circular truncated cone, and the vertex angle ex of the isosceles trapezoid in the longitudinal section is 30 to 80. The joint between the second reaction zone and the exit zone has a circular truncated cone shape, and its longitudinal section isosceles trapezoidal The bottom angle β is 45 to 85 °. In order to implement the present invention, a new riser reactor and a catalyst cooler as described above need to be added to the original catalytic cracking device. The original riser reactor is used as a gasoline riser reactor for the conversion of gasoline fractions; the new riser reactor is used as a raw oil riser reactor for cracking conventional catalytic cracking raw materials. The gasoline fraction is reacted in a gasoline riser, and the generated reaction gas and catalyst mixture is introduced into the second reaction zone of the raw oil riser as a cold shock medium. The reaction oil and gas and the waiting catalyst in the raw oil riser enter the settler through their exit zone; the reaction oil and gas enter the subsequent separation system for separation, and the separated crude gasoline can be partially returned as the raw material of the gasoline riser. After being stripped and regenerated, the waiting catalyst is divided into two parts, one part of which is returned to the raw oil riser, and the other part is cooled and returned to the gasoline riser.

The five embodiments listed in the first solution of the present invention are described below with reference to the accompanying drawings, but the first solution of the present invention is not limited by the description of the following drawings.

FIG. 1 is a schematic flowchart of the embodiment A. As shown in Figure 1, the pre-heated gasoline fraction goes through the pipeline

1 Enter the bottom of the riser 2 and mix and react with the regenerant from the regeneration inclined pipe 17. The reaction stream enters the settler 7 with or without a dense-phase fluidized bed reactor, and the reaction oil and gas and water vapor pass through the line 8 Enter the subsequent product separation system. The regenerant enters the stripper 3, and the reaction oil and gas carried by the regenerant is stripped by water vapor from the line 4. The stripped regenerant enters the regenerator 1 3 through the oblique pipe 5 and the oxygen-containing gas passes through Line 14 is introduced into the regenerator, and the regenerant is burned and regenerated under the action of oxygen-containing gas. The regeneration flue gas is led out of the regenerator through line 12, and the high-temperature regenerant enters the catalyst cooler 16 through line 15. The cooled regenerant The regeneration inclined pipe 17 is returned to the bottom of the riser for recycling, and the loose air enters the catalyst cooler 16 through the pipeline 18.

FIG. 2 is a schematic flowchart of Embodiment B. FIG. As shown in FIG. 2, the pre-heated gasoline fraction enters the bottom of the riser 2 through line 1 and is mixed and reacted with the regeneration agent from the regeneration inclined pipe 17, and the reaction stream enters the fluidized bed reactor with or without dense phase. The settler 27 realizes the separation of reaction oil and gas and catalyst. At the same time, the pre-lifting medium enters from the bottom of the raw oil riser 22 through the line 20, and the high-temperature regenerant enters the bottom of the riser 22 through the regeneration inclined pipe 19, and is lifted by the pre-lifting medium. The pre-heated conventional cracked raw material passes the line 21 It is injected into the riser 22, mixed with the high-temperature regenerant, and reacted, and the reaction stream enters the settler 27 with or without a dense-phase fluidized-bed reactor to realize separation of reaction oil, gas and catalyst. The reaction oil and gas enters the subsequent separation system through line 28 to realize separation of dry gas, liquefied gas, gasoline, diesel and heavy oil. The standby agent enters the stripper 23, and the reaction oil and gas carried by the standby agent is stripped by water vapor from the line 24. The stripped standby agent enters the regenerator 1 3 through the standby inclined pipe 25, and the oxygen-containing gas The regenerator is introduced through line 14 and the regenerant is burned and regenerated under the action of oxygen-containing gas. The regenerated flue gas is led out of the regenerator through line 12 to divide the high-temperature regenerant into two parts, of which a part of the regenerant enters through line 15 The catalyst cooler 16, the cooled regenerant is returned to the bottom of the riser by the regeneration inclined pipe 17 Use; the other part of the regenerant returns to the raw oil riser 22 via the regeneration oblique tube 19. The loose air from the catalyst cooler enters through line 18.

FIG. 3 is a schematic flowchart of Embodiment C. FIG. As shown in FIG. 3, the preheated gasoline fraction enters the bottom of the gasoline riser 2 through line 1, and is mixed and reacted with the regenerant from the regeneration inclined pipe 17. The reactant stream enters the fluidized bed reaction with or without dense phase. The settler 7 of the reactor realizes the separation of reaction oil, gas and catalyst. The reaction oil, gas and water vapor enter the separation system 9 through line 8, the gas and gasoline products are led out through line 10, and the diesel products are led out through line 11. At the same time, the pre-lifting medium enters from the bottom of the raw oil riser 22 through line 20. The high-temperature regenerated catalyst enters the bottom of the riser 22 through the regeneration inclined pipe 19 and is lifted by the pre-lifting medium; the pre-heated conventional cracking raw material enters the bottom of the riser 22 through the line 21 and is mixed with the high-temperature regenerated catalyst to react. The reactant stream enters the settler 27 with or without a dense-phase fluidized-bed reactor; the reaction oil, gas, and water vapor of conventional cracked feedstock enters the subsequent separation system via line 28 to realize the dry gas, liquefied gas, gasoline, diesel, and Separation of heavy oil. The reaction oil, gas, and water vapor from the gasoline riser can also be mixed with the reaction oil, gas, and water vapor from the raw oil riser through line 32 and entered into the subsequent separation system through line 28 to realize the dry gas, liquefied gas, gasoline, and diesel oil. And separation of heavy oil. The gasoline catalyst riser enters the stripper 3, and is stripped by the water vapor from the line 4, and then enters the regenerator 13 through the inclined ramp 5; the raw oil riser catalyst enters the stripper 23, and Water vapor stripping from line 24; the stripped catalyst enters regenerator 13 through inclined tube 25 to be regenerated; or stripper 3 and 23 are connected through line 33 so that the above two types of regenerated catalyst are in the stripper together Complete the stripping process in step 23. The air enters the regenerator 13 through the line 14 and the catalyst to be scorched is regenerated in the air. The regenerated flue gas is led out from the line 12. The high-temperature regenerant is divided into two parts, one of which returns to the raw oil riser 22 through the regeneration inclined pipe 19; the other part enters the cooler 16 through the pipeline 15 and after cooling in a conventional manner, the regeneration inclined pipe 17 returns to the gasoline riser 2 for circulation use. The loose air enters the catalyst cooler 16 through the line 18.

FIG. 4 is a schematic flowchart of Embodiment D. FIG. As shown in FIG. 4, the light gasoline fraction (boiling point range 40 ~ 100 ° C) after preheating enters the bottom of gasoline riser 2 through line 1 and is mixed with the regenerant from regeneration inclined pipe 17 to react. The heavy gasoline fraction (The boiling point ranges from 100 to 20 (TC) and is injected into the middle and upper part of the riser 2 through line 34. The reaction stream enters the settler 27 with or without a dense-phase fluidized-bed reactor. At the same time, the pre-lifting medium passes The pipeline 20 enters from the bottom of the raw oil riser 22, and the high-temperature regenerant enters the bottom of the riser 22 through the regeneration inclined pipe 19 and is lifted by the pre-lifting medium. The pre-heated conventional cracked raw materials enter the bottom of the riser 22 through the line After reacting with the regenerant, the reaction stream enters the settler 27 with or without a dense-phase fluidized-bed reactor. The reaction oil and gas enters the subsequent separation system via line 28 to realize the dry gas, liquefied gas, gasoline, Separation of diesel oil and heavy oil. The waiting catalyst enters the stripper 23, is stripped by the water vapor from the line 24, and enters the re-entering inclined pipe 25 to enter 生器 13。 The device 13. The waiting catalyst is burned and regenerated in the air, the air enters the regenerator 13 through the line 14, the regenerated flue gas is led out through the line 12, and the high-temperature regenerant is divided into two parts, one of which is returned to the raw oil riser 22 through the regeneration inclined pipe 19, The other part is cooled by the catalyst cooler 16 in the pipeline 15 and then returned to the gasoline riser 1 for recycling through the regeneration inclined pipe 17. The loose air enters the catalyst cooler 16 through the pipeline 18.

FIG. 5 is a schematic flowchart of Embodiment E. FIG. As shown in Figure 5, the preheated gasoline

1 enters the bottom of the gasoline riser 2 and reacts with the cooled regenerant from the regeneration inclined pipe 17, and the generated reaction stream is injected into the second reaction zone c of the new raw oil riser 22. At the same time, the pre-lifting medium enters from the bottom of the new type riser pipe 22 through the pipeline 20, and the high-temperature regenerant enters the pre-lifting section a of the riser pipe 22 through the regeneration inclined pipe 19, and is lifted by the pre-lifting medium; conventional cracking after preheating The raw materials enter the raw material oil riser 22 through line 21, are mixed with the high-temperature regenerant in the riser, and are reacted in the first reaction zone b of the riser; the generated reaction stream enters the second reaction zone c, and comes from gasoline The reaction streams from riser 2 are mixed and subjected to a secondary reaction. The above-mentioned reaction stream enters the settler 27 through the exit zone d and the horizontal pipe e of the riser 22 to separate the reaction oil and gas from the catalyst; the reaction oil and gas enter the subsequent separation system through line 28 to realize the dry gas, liquefied gas, gasoline, diesel, and Separation of heavy oil. The standby agent falls into the stripper 23 from the settler 27, and is stripped by the water vapor from the line 24, and then sent to the regenerator 13 through the standby inclined pipe 25. The regenerant is burned and regenerated in the regenerator, the regeneration air is introduced into the regenerator through the line 14 and the regeneration flue gas is led out through the line 12. The high-temperature regenerant is divided into two parts, one of which is sent to the riser 22 for recycling through the regeneration inclined pipe 19; the other part enters the catalyst cooler 16 through the line 15 and the cooled regenerant is returned to the gasoline riser 2 by the regeneration inclined pipe 17 for circulation use. The loose air of the catalyst cooler 16 is introduced through a line 18.

The catalyst used in scheme two is a catalyst having a coke deposit amount of 0.10 to 0.90% by weight and a temperature lower than 600 ° C, and the catalyst is selected from one of the following five types of catalysts: ① semi-regenerated catalyst; ② Mixture of semi-regenerated catalyst and regenerated catalyst; ③ Mixture of catalyst to be grown and regenerated catalyst; ④ Mixture of catalyst to be grown, semi-regenerated catalyst and regenerated catalyst; ⑤ Incompletely regenerated catalyst in single stage regeneration. 10〜0. 90 重量％的溶液 ’s contact, at a reaction temperature of 300, the preheated gasoline fraction enters the riser or fluidized bed reactor of the gasoline catalytic converter ~ 600 ° C, reaction pressure 130 ~ 450Kpa, weight hourly space velocity l ~ 120h- weight ratio of catalyst to gasoline distillate is 2 ~ 15, weight ratio of water vapor to gasoline distillate is 0 ~ 0.1 The preferred reaction conditions are as follows: reaction temperature 350 ~ 550 ° (; reaction pressure 250 ~ 400Kpa, weight hourly space velocity 2 ~ 100h- weight ratio of catalyst to gasoline fraction 3 ~ 10, weight of water vapor and gasoline fraction The ratio is 0.01 to 0.05. The reaction product, water vapor, and the carbon-containing catalyst after the reaction are subjected to gas-solid separation; the reaction product is separated to obtain a dry gas, a liquefied gas rich in propylene and isobutyrium, and an isofluorene-rich The main products of hydrocarbons and aromatics such as gasoline and diesel oil; the waiting agent enters the stripping section, and the hydrocarbon products adsorbed on the catalyst are extracted with water vapor, and then sent to the regenerator to be burned and regenerated in the presence of oxygen-containing gas. The above reaction process can be implemented separately on a gasoline catalytic conversion device, or can be implemented in combination with a riser catalytic cracking device or a fluidized bed catalytic cracking device that processes conventional catalytic cracking raw materials, that is, processing conventional catalytic cracking raw materials according to the requirements of the present invention The device is slightly modified, so that the gasoline fraction and the conventional catalytic cracking raw materials are first reacted in their respective reactors; and the separation of the reaction oil and gas and the catalyst, the separation of the reaction products, and the stripping process with the carbon-containing catalyst after the reaction can be the above two. Each of the reaction streams can be carried out separately, and the two reaction streams can also be combined together to perform the regeneration; the catalysts separated from the two streams can be regenerated together, that is, a common regeneration system is shared.

Six specific embodiments are listed below to further explain the process described in Scheme 2, but Scheme 2 of the present invention is not limited to any specific embodiments below.

Embodiment F: When implemented separately on a gasoline catalytic conversion device converted from an idle riser catalytic cracking device, the amount of coke deposited by the regenerator is incompletely regenerated from 0.1 to 0.90 wt% catalyst and pre The heated gasoline feedstock enters the riser reactor or fluidized bed reactor, and performs the reaction in the presence or absence of water vapor; reacts the oil and gas, water vapor, and the reacted regenerant to perform gas-solid separation; separates the reaction products to obtain gasoline products 10 ~ 0. 90 and a small amount of dry gas, liquefied gas, diesel oil; the agent to be regenerated is subjected to steam stripping and input to the regenerator, and the char is regenerated in the presence of oxygen-containing gas; After being cooled, the catalyst is returned to the reactor for recycling.

Embodiment G: For a catalytic cracking unit of a single riser reactor, a new riser reactor is required. The new riser reactor shares the original settler, stripper, subsequent separation system and regeneration system with the original riser reactor. The raw material of the newly built reactor is gasoline fraction, which is called a gasoline riser; the raw material of the original reactor is a conventional cracked raw material, and the reactor is called a raw oil riser. Gasoline feedstock and conventional cracked feedstock are reacted in the gasoline riser and raw oil riser, respectively, and the mixture of reaction oil, gas and catalyst enters the settler and subsequent separation system. The separated crude gasoline can be partially returned and used as the raw material of the gasoline riser. The waiting catalyst is regenerated after being stripped. The semi-regenerated catalyst in the first regenerator is divided into two parts, one of which enters the second regenerator and continues to burn off coke remaining on the catalyst, and the other part of the semi-regenerated catalyst enters the catalyst cooler and returns to the gasoline riser after cooling; and the second The regenerated catalyst in the regenerator is returned to the feed oil riser.

Embodiment H: For a catalytic cracking device of a single riser reactor, a new fluidized bed reactor with or without a riser needs to be newly built, and the reactor may be provided with or without a stripping section. The newly built reactor shares the regenerator with the original reactor. The raw material of the newly built reactor is gasoline fraction, which is called a gasoline reactor; the raw material of the original reactor is a conventional cracking raw material, and the reactor is called a raw oil riser reactor. Gasoline fractions and conventional cracked raw materials are reacted in a gasoline reactor and a feed oil riser reactor, respectively; the reaction oil and gas generated from gasoline fractions and the reaction oil and gas generated from conventional cracked materials are mixed into a subsequent separation system, or separately into their respective subsequent In the separation system, the separated crude gasoline can be partially returned as the raw material of the gasoline riser. The waiting catalyst is regenerated after being stripped. Inside the first regenerator The regenerated catalyst is divided into two parts, one of which enters the second regenerator and continues to burn off coke remaining on the catalyst, and the other part of the regenerated catalyst enters the catalyst cooler and returns to the gasoline reactor after cooling; and the regenerated catalyst in the second regenerator returns Raw oil riser.

Embodiment I: The method provided by the present invention can also be implemented by combining a new type of riser reactor with a conventional catalytic cracking device. This new riser reactor is the same as the new riser reactor described in Embodiment E. In order to implement the present invention, a new riser reactor and a catalyst cooler as described above need to be added to the original catalytic cracking device. The original riser reactor was used as a gasoline riser reactor for the conversion of gasoline fractions; the new riser reactor was used as a raw oil riser reactor to crack conventional catalytic cracking raw materials. Gasoline fractions are reacted in a gasoline riser, and the resulting mixture of reaction oil and catalyst is introduced into the second reaction zone of the raw oil riser as a cold shock medium. The reaction oil and gas and the waiting catalyst in the raw oil riser enter the settler through their exit zone; the reaction oil and gas enter the subsequent separation system for separation, and the separated crude gasoline can be partially returned as the raw material of the gasoline riser. The waiting catalyst is regenerated after being stripped. The semi-regenerated catalyst in the first regenerator is divided into two parts, one of which enters the second regenerator and continues to burn off coke remaining on the catalyst, and the other part of the semi-regenerated catalyst enters the catalyst cooler and returns to the gasoline riser after cooling; and the second The regenerated catalyst in the regenerator is returned to the feed oil riser.

Embodiment J: For a catalytic cracking unit of a single riser reactor, a new riser reactor is required. The newly built reactor shares the settler, stripper, subsequent separation system and regeneration system with the existing reactor. The raw material of the newly-built riser reactor is gasoline fraction, and the reactor is called gasoline riser; the raw material of the original riser reactor is conventional cracked raw material, and the reactor is called raw oil riser. Gasoline raw materials and conventional cracked raw materials are reacted in the gasoline riser and raw oil riser, respectively, and the generated reaction oil and gas enters the settler and subsequent separation system for separation. The separated crude gasoline can be partially returned as the raw material of the gasoline riser; The waiting catalyst is regenerated after being stripped. The semi-regenerated catalyst in the first regenerator is divided into two parts, one of which enters the second regenerator and continues to burn off coke remaining on the catalyst, and the other part of the semi-regenerated catalyst is cooled by the cooler and enters the catalyst mixing tank to be mixed with the partially regenerated catalyst After that, it enters the gasoline riser; the rest of the regenerated catalyst in the second regenerator is returned to the raw oil riser.

Embodiment 10 K: When implemented separately on a gasoline catalytic conversion device, the regenerated catalyst after the regeneration is moderately regenerated and the stand-by catalyst from the stripping section is first fully mixed in the catalyst mixer to form a coke deposit amount of 0. 10 ~ 0.90% by weight of mixed catalyst; the mixed catalyst is divided into two parts, and a part of the mixed catalyst is passed through a catalyst cooler, the temperature of which is lowered below 600 ° C, and then sent to a riser reactor or a fluidized bed reactor, and The preheated gasoline feedstock is reacted in the presence or absence of water vapor, and another part of the mixed catalyst is sent to the regenerator to be burned and regenerated in the presence of oxygen-containing gas; the reaction oil and gas, water vapor, and the reacted regenerant are carried out. Gas-solid separation; separation of reaction products to obtain gasoline products and a small amount of Dry gas, liquefied gas, diesel oil; the agent to be stripped is sent to the catalyst mixer after being stripped with water vapor, mixed with the regenerated catalyst and recycled.

The six embodiments listed in the second embodiment of the present invention are described below with reference to the accompanying drawings, but the second embodiment of the present invention is not limited by the description of the following drawings.

FIG. 1 is a schematic flowchart of Embodiment F. As shown in FIG. 1, when the present invention is implemented separately on a gasoline catalytic conversion device, the amount of coke deposited in the regenerator 13 is not fully regenerated from 0. 10-0. 90% by weight of the catalyst from line 15 into the catalyst cooler 16. After cooling, it is transported from the catalyst line 17 to the riser reactor 2. The pre-heated gasoline fraction enters the bottom of the riser reactor 2 through line 1 and reacts in the presence of water vapor; the reacted oil and gas, water vapor, and reacted regenerant undergo gas-solid separation in a settler 7; reaction The product is transported to the subsequent separation system via the oil and gas pipeline 8 and further separated into gasoline products and a small amount of dry gas, liquefied gas, and diesel. The standby agent falls into the stripper 3, and the water vapor is introduced into the stripper 3 through the line 4. The stripped standby agent is sent from the line 5 to the regenerator 1 3 to be burned for regeneration. The oxygen-containing gas is introduced into the regenerator 13 from the line 14, and the regenerated flue gas enters the subsequent energy recovery system through the line 12; the amount of carbon deposited after the regeneration is 0.1 to 0.90% by weight of the catalyst is returned to the reactor 2 through the cooler 16 recycle. The loose air enters the catalyst cooler 16 through the line 18.

FIG. 6 is a schematic flowchart of Embodiment G. FIG. As shown in FIG. 6, the preheated gasoline feed enters the bottom of the riser 2 through line 1 and is mixed with the semi-regenerated catalyst from the semi-regenerated inclined pipe 17 to perform the reaction, and the reactant stream enters with or without dense phase fluidization. Bed reactor settler 27. At the same time, the pre-lifting medium enters from the bottom of the raw oil riser 22 through the line 20, and the high-temperature regeneration catalyst enters the bottom of the riser 22 through the regeneration inclined pipe 19 and is lifted by the pre-lifting medium; the conventionally cracked raw materials after preheating It enters the bottom of the riser 22 through the line 21, and is mixed with the high-temperature regenerated catalyst for reaction, and the reaction stream enters the settler 27 with or without a dense-phase fluidized bed reactor. The above-mentioned reaction oil and gas, pre-lift medium and water vapor enter the subsequent separation system through line 28 to realize the separation of dry gas, liquefied gas, gasoline, diesel and heavy oil. The waiting catalyst enters the stripper 23 and is stripped by water vapor from the line 24; the stripped catalyst enters the first regenerator 1 3.1 through the waiting inclined pipe 25. The air enters the first regenerator 13.1 and the second regenerator 13.2 through the line 14. The catalyst to be regenerated is burned and regenerated in the air, and the regeneration flue gas is led from the first regenerator 13.1 and the second regeneration through the line 12.器 1 3.2. The hot semi-regenerated catalyst is divided into two parts, one of which enters the second regenerator 13.2 for complete regeneration, and the regenerated catalyst returns to the raw oil riser 22 through the regeneration inclined pipe 19; the other part enters the cooler 16 through the line 15, according to the conventional After the method is cooled, the semi-regenerative inclined pipe 17 is returned to the gasoline riser 2 for recycling. Loose air enters cooler 16 through line 18.

FIG. 7 is a schematic flowchart of Embodiment H. FIG. As shown in FIG. 7, the pre-heated gasoline fraction enters the bottom of the gasoline riser 2 through the line 1 and is mixed with the semi-regenerated catalyst from the semi-regenerated inclined pipe 17 and then carried out. Reaction; the mixture of reaction oil and gas and the catalyst enters the settler 7 with or without a dense-phase fluidized bed reactor; the reaction oil and gas and water vapor enter the separation system 9 through a line 8; the gas and gasoline products are led out through a line 10; diesel The product is led out via line 11. At the same time, the pre-lifting medium enters from the bottom of the raw oil riser 22 through the line 20, and the high-temperature regeneration catalyst enters the bottom of the riser 22 through the regeneration inclined pipe 19, and is lifted by the pre-lifting medium; the conventionally cracked raw materials after preheating It enters the bottom of the riser 22 through line 21 and is mixed with the high-temperature regeneration catalyst for reaction. The reaction stream enters the settler 27 with or without a dense-phase fluidized-bed reactor; The medium and water vapor enter the subsequent separation system through line 28 to realize the separation of dry gas, liquefied gas, gasoline, diesel and heavy oil. The reaction oil, gas, and water vapor from the gasoline riser can also be mixed with the reaction oil, gas, and water vapor from the raw oil riser through line 32 and entered into the subsequent separation system through line 28 to realize the dry gas, liquefied gas, gasoline, and diesel oil. And separation of heavy oil. The gasoline catalyst riser enters the stripper 3, and is stripped by the water vapor from the line 4, and then enters the first regenerator 1 3.1 by the waste inclined pipe 5; the raw catalyst riser enters the steam. The stripper 23 is stripped by water vapor from the line 24; the stripped catalyst enters the first regenerator 1 3.1 through the inclined pipe 25 to be produced; or the strippers 3 and 23 are connected through the line 33 so that the above The two stand-by catalysts jointly perform the stripping process in the stripper 23. The air enters the first regenerator 13.1 and the second regenerator 13.2. Through the line 14. The catalyst to be regenerated is burned in the air to be regenerated, and the regenerated flue gas is led from the first regenerator 13.1 and the second regeneration through the line 12.器 1 3.2. The hot semi-regenerated catalyst is divided into two parts, one of which enters the second regenerator 13.2 for complete regeneration, and the regenerated catalyst returns to the raw oil riser 22 through the regeneration inclined pipe 19; the other part enters the cooler 16 through the line 15, according to the conventional After the method is cooled, the semi-regenerative inclined pipe 17 is returned to the gasoline riser 2 for recycling. The loose air enters the cooler 16 through the line 18.

FIG. 8 is a schematic flowchart of the first embodiment. As shown in FIG. 8, the pre-heated gasoline fraction enters the bottom of the gasoline riser 2 through the line 1, and the cooled semi-regenerated catalyst enters the bottom of the riser 2 through the semi-regenerated inclined pipe 17 to react with the gasoline fraction. The stream enters the second reaction zone c of the new feed oil riser 22. At the same time, the pre-lifting medium enters from the bottom of the new raw material oil riser 22 through the line 20, and the high-temperature regeneration catalyst enters the pre-lifting section a of the raw oil riser 22 through the regeneration inclined pipe 19, and is lifted by the pre-lifting medium. The pre-heated conventional cracked feedstock enters the feedstock riser 22 via line 21, and is mixed with the high-temperature regenerated catalyst to react in the first reaction zone b of the feedstock riser 22, and the reaction stream enters the second reaction zone c of the riser 22 Mixed with the reactant stream from the gasoline riser 1. The reaction oil and gas and the catalyst to be generated enter the settler 27 through the horizontal pipe e in the exit zone of the riser 22, and the reaction oil and gas and water vapor enter the subsequent separation system through the line 28 to realize the separation of dry gas, liquefied gas, gasoline, diesel and heavy oil. The waiting catalyst enters the stripper 23 and is stripped by water vapor from the line 24; the stripped catalyst enters the first regenerator 13.1 through the waiting inclined pipe 25. Air enters the A regenerator 13.1 and a second regenerator 13.2 are prepared by scorching the catalyst in the air, and the regenerated flue gas is led out from the first regenerator 13.1 and the second regenerator 13.2. The hot semi-regenerated catalyst is divided into two parts, one of which enters the second regenerator 13.2 for complete regeneration, and the regenerated catalyst returns to the raw oil riser 22 through the regeneration inclined pipe 19; the other part enters the cooler 16 through the line 15 and is cooled according to the conventional method After that, it is returned to the gasoline riser 2 for recycling by the semi-regenerated inclined pipe 17. The loose air enters the cooler 16 through the line 18.

FIG. 9 is a schematic flowchart of Embodiment J. FIG. As shown in FIG. 9, the preheated gasoline fraction enters the bottom of riser 2 through line 1 and contacts and reacts with the fully mixed semi-regenerated catalyst and regenerated catalyst through catalyst mixing tank 36 and line 37, and the reaction stream enters Settler 27 with or without dense phase fluidized bed reactor. At the same time, the pre-lifting medium enters through the line 20 and from the bottom of the raw oil riser 22, and the high-temperature regeneration catalyst enters the bottom of the riser 22 through the regeneration inclined pipe 19, and is lifted by the pre-lifting medium, and the conventional cracking after preheating The raw material enters the bottom of the riser 22 through the line 21, contacts and reacts with the high-temperature regenerated catalyst, and the reaction stream enters the settler 27 with or without a dense-phase fluidized-bed reactor. The reaction oil, gas and water vapor enter the subsequent separation system through line 28 to realize the separation of dry gas, liquefied gas, gasoline, diesel and heavy oil. The waiting catalyst enters the stripper 23 and is stripped by water vapor from the line 24; the stripped catalyst enters the first regenerator 13.1 through the waiting inclined pipe 25. The regeneration air enters the first regenerator 13.1 and the second regenerator 13.2 through the line 14. The catalyst to be regenerated is burned and regenerated in the air, and the regeneration flue gas is led from the first regenerator 13.1 and the second regenerator 13.2 through the line 12. The hot semi-regenerated catalyst is divided into two parts, one of which enters the second regenerator 13.2 for complete regeneration; the other part enters the cooler 16 through the line 15 and is cooled by the conventional method by the semi-regenerated inclined pipe 17 and sent to the catalyst mixing tank 36; The completely regenerated high-temperature regeneration catalyst in the second regenerator 13.2 is also divided into two parts. One part is returned to the raw material oil riser 22 through the regeneration inclined pipe 19; the other part enters the catalyst mixing tank 36 through the line 35, and the half from the catalyst cooler 16 The regenerated catalyst is thoroughly mixed; the obtained mixed catalyst is returned to the gasoline riser 2 for recycling. The loose air enters the catalyst cooler 16 through the line 18.

FIG. 10 is a schematic flowchart of Embodiment K. FIG. As shown in FIG. 10, when the present invention is implemented separately on a gasoline catalytic conversion device, the regenerated catalyst after being regenerated in the regenerator 13 moderately enters the catalyst mixer 38 through the line 39, and is sufficient with the waiting catalyst input through the line 40 Mix to form a mixed catalyst with a coke deposit of 0.10 to 0.90% by weight. The mixed catalyst is divided into two parts, one of which is sent to the regenerator 13 through the line 41 to be burned for regeneration, the oxygen-containing gas is introduced into the regenerator 13 through the line 14, and the regenerated flue gas enters the subsequent energy recovery system through the line 12. The other part of the mixed catalyst enters the catalyst cooler 16 through the line 42 to reduce the temperature of the mixed catalyst to below 600 ° C., and then is sent to the riser reactor 2 through the line 43. The preheated gasoline fraction enters the bottom of riser reactor 2 through line 1, In contact with the mixed catalyst, the reaction is performed in the presence of water vapor. The reacted oil and gas, water vapor, and the reacted regenerant undergo gas-solid separation in the settler 7. The reaction products are transported to the subsequent separation system via the oil and gas pipeline 8 and further separated into gasoline products and a small amount of dry gas, liquefied gas, and diesel. The standby agent falls into the stripper 3, and the water vapor is introduced into the stripper 3 through the line 4. The stripped standby agent is sent to the catalyst mixer 38 through the line 40 and mixed with the regenerated catalyst input from the line 39 again. A mixed catalyst with a carbon deposition amount of 0.10 to 0.90% by weight is used to cycle the above reaction and regeneration process. The loose air enters the catalyst cooler 16 through the line 18.

The catalyst used in scheme three is a catalyst to be produced with a carbon deposition amount of 0.90 ~ 2.0% by weight. The implementation steps are as follows: After completing the conventional reaction process, the catalytic cracking catalyst enters the settler stripping section, and the The heated gasoline fractions are in contact at 400 ~ 550. (：, 130 ~ 450Kpa, heavy hourly space velocity l ~ 50h- weight ratio of catalyst to gasoline distillate is 3 ~ 20, weight ratio of water vapor to gasoline distillate is 0.03 ~ 0. 30; conditions occur; preferably The reaction conditions are as follows: reaction temperature 420 ~ 520 ° (:, reaction pressure 250 ~ 400Kpa, weight hourly space velocity 2 ~ 40h- weight ratio of catalyst to gasoline fraction 4 ~ 18, weight ratio of water vapor to gasoline fraction 0 05 ~ 0. 30; Isolate the reaction product, and regenerate the catalyst after the reaction.

In the third embodiment, the stripping section of the catalytic cracking unit needs to be modified according to the following steps:

(1) A gasoline distillate feed port is provided in the settler stripping section. For a conventional settler stripping section, the height of the catalyst dense phase bed in the stripping section is taken as 100%, and the uppermost end of the bed is used as the initial position. The gasoline distillate inlet should be located at the height of the dense phase bed. 10 ~ 60%, preferably 15 ~ 55%; for the stripping section which is integrated with the dense phase bed of the catalyst in the fluidized bed reactor and the container which plays the role of catalyst stripping in the catalytic cracking device, the invention; The total height of the dense-phase catalyst bed is taken as 100%, and the uppermost end of the bed is still used as the initial position. The choice of the position of the gasoline distillate feed port is the same as that of the conventional settler stripping section.

(2) The gasoline fraction can flow through the above-mentioned inlet through any feeding method. For example, it can be through a distribution ring or an atomizing nozzle provided in the stripping section, or it can strip part of the original steam in the stripping section. The inlet is converted into a gasoline distillate feed inlet as long as the gasoline distillate can be uniformly dispersed in the catalyst dense phase bed.

(3) When the catalytic cracking unit is operating normally, the gasoline fraction injected into the dense phase bed of the catalyst in the stripping section may be atomized steam or not. However, the gasoline distillate feed line needs to be connected to the steam line, and additional flow control valves should be added to the gasoline and steam lines to increase operational flexibility.

The specific process L is used to further describe the process described in the third embodiment, but the third embodiment of the present invention is not limited to the specific embodiments hereinafter.

The specific steps of Embodiment L are briefly described as follows:

(1) The coked catalyst that has completed the conventional catalytic cracking reaction process falls into the settler stripping section, and The preheated gasoline fraction reacts in the middle and upper part of the stripping section.

(2) The catalyst that reacts with the gasoline fraction in the stripping section gradually moves to the middle and lower parts of the stripping section under the pressure balance of the reaction-regeneration system; through the catalyst baffle and single-stage or The multi-stage steam inlet contacts the catalyst and steam in countercurrent to replace the oil and gas generated by the above-mentioned reaction adsorbed in the catalyst pores and between the catalyst particles. In order to enhance the stripping effect in the middle and lower part of the stripping section and reduce the hydrogen content in the coke, the amount of stripping steam and / or the catalyst storage in the stripping section can be appropriately increased.

(3) The reaction product of the gasoline fraction and the reaction product of the conventional catalytic cracking are introduced into the subsequent separation system from the top of the settler for product separation. The obtained gasoline product can be partially returned to the stripping section as the gasoline feedstock of the present invention.

(4) The catalyst to be prepared to complete the above-mentioned stripping process is sent to the regenerator through the inclined tube to be regenerated, and is burned and regenerated under the action of oxygen-containing gas. The regenerated catalyst is returned to the reaction system, and first reacts with the conventional catalytic cracking raw materials. The coke-accumulated catalyst after the reaction falls into the settler stripping section for recycling.

Embodiment L is further described below with reference to the accompanying drawings, but the third solution of the present invention is not limited by the following accompanying drawings.

As shown in FIG. 11, the pre-lifting medium enters from the bottom of the riser 22 through the line 21, and the high-temperature regeneration catalyst enters the bottom of the riser through the regeneration inclined pipe 19 to be lifted by the pre-lifting medium. The preheated conventional catalytic cracking feedstock oil and atomized steam enter the riser via line 21, mix with the high-temperature regeneration catalyst, and react. After the mixture of reaction oil, gas and catalyst is initially separated by the gas-solid separation system 7, the reaction oil and gas is introduced into the separation system through the settler 27 and the pipeline 28. The charred catalyst after the reaction enters the stripping section 23. The gasoline fraction is injected into the stripping section 23 through the line 5 and comes into countercurrent contact with the catalyst with carbon and reacts. The oil and gas generated by the reaction enter the settler 27 under the action of stripping steam, and are mixed with the oil and gas generated by the conventional catalytic cracking reaction and enter the subsequent separation system. The catalyst in the stripping section 23, which has completed the above reaction, continues to descend along the stripping section 23, and the stripping steam is introduced from the lower part of the stripping section through the line 24 to replace the reaction oil and gas adsorbed by the catalyst particles. The stripped catalyst to be regenerated is burned and regenerated into the regenerator 13 through the inclined pipe 25 to be regenerated. The oxygen-containing gas used for regeneration enters the regenerator 1 3 through the line 14 and the regenerated flue gas is discharged through the line 12. The high-temperature regenerated catalyst is recycled to the bottom of the riser 22 through the regenerated inclined pipe 19 for recycling.

Fig. 12 and Fig. 13 show two different forms of stripping section 23 in scheme three. Figure 12 is a conventional catalytic cracking stripping section, and Figure 13 is a stripping section with a fluidized bed reactor.

Compared with the prior art, the method provided by the present invention has the following characteristics:

1. Gasoline fractions or narrow fractions of gasoline fractions with an olefin content of 10 to 90% by weight and high sulfur and nitrogen contents can be used as the raw materials of the present invention. Therefore, the raw material range of the present invention is relatively broad. A gasoline fraction with poor properties that cannot be used directly as a blending component in commercial gasoline, for example, catalytic Gasoline, coking gasoline, visbreaked gasoline, cracked gasoline, straight run gasoline, etc., after being processed by the method provided by the present invention, can all be used as blending components of commercial gasoline to produce gasoline products that meet the latest specifications.

2. The invention has no special requirements for the catalyst, and many different types of catalytic cracking catalysts are applicable to the invention. In particular, it should be noted that when the present invention is implemented alone, an equilibrium catalyst discharged from a catalytic cracking unit may be used. In this way, the invention not only improves the quality of gasoline fractions, but also can effectively reduce operating costs.

3. The present invention uses a more flexible device type, which can be implemented alone or in combination with an existing catalytic cracking device. It is very common for many refineries to have more than two catalytic cracking units. However, in order to solve the problem of raw material shortage or to reduce costs, form a certain processing scale, and improve economic benefits, many refineries have idled one or two FCC units. Therefore, the present invention can be implemented using an existing, idle catalytic cracking unit of a refinery.联合 The modification of the existing catalytic cracking unit is also relatively small by joint implementation. It can share the settler, stripper, subsequent separation system and regeneration system with the existing catalytic cracking unit, and only needs to add a riser for gasoline fractions. Reactor or fluidized bed reactor. Therefore, less construction investment is required for the present invention.

4. Using the method provided by the present invention to process the above gasoline fractions, in the obtained material balance, the gasoline yield accounts for about 80% by weight, and the rest is dry gas, liquefied gas, diesel and coke, and the olefins of the obtained gasoline product The content is less than 26% by weight. In addition, the desulfurization rate of the method provided by the present invention can reach about 80%, and the denitrification rate can reach about 98%. Therefore, the implementation effect of the present invention is relatively obvious. After the inferior gasoline fraction is processed by the present invention, it can become an ideal commercial gasoline blending component. Examples

The following examples will further illustrate the present invention, but the invention is not limited thereby. The properties of the catalysts and feedstock oils used in the examples are shown in Tables 1 and 2, respectively. The catalysts in Table 1 are all produced by the catalyst plant of Qilu Petrochemical Company of China Petroleum and Chemical Corporation.

Example 1

This example illustrates a case where the method of the first solution provided by the present invention is used to catalytically convert gasoline olefins in a small fluidized bed reactor using different types of catalysts.

The gasoline A listed in Table 2 was used as a raw material, and four different types of catalysts listed in Table 1 were used to perform a gasoline catalytic conversion reduction olefin test in a small-scale fluidized bed reactor for continuous reaction regeneration operation. Gasoline fraction A is mixed with high-temperature water vapor and enters a fluidized bed reactor. The reaction temperature is 300 ° C, the pressure at the top of the reactor is 0.2 MPa, the weight hourly space velocity is 4 hours, and the agent-oil ratio is 6, 7j. Oil ratio of 0.03 The catalyst is contacted with the catalyst under the conditions to perform the catalytic conversion reaction. The reaction product, steam and the catalyst to be produced are separated in a settler, and the reaction product is separated to obtain a gas product and a liquid product. The catalyst to be produced enters the stripper, and the hydrocarbon products adsorbed on the catalyst to be produced are extracted by water vapor. The stripped catalyst enters the regenerator and comes into contact with the heated hot air for regeneration. The regenerated catalyst is cooled and returned to the reactor for recycling. The test conditions, test results, and properties of gasoline are listed in Table 3.

It can be seen from Table 3 that different types of catalysts have a certain effect on the results of catalytic conversion reactions of gasoline feedstocks. The isofluorene in the gasoline composition accounts for 42.3 to 54.0% by weight, the aromatic hydrocarbons account for 25.0 to 26.6% by weight, and the olefins account for only 8.7 to 18.4% by weight, and the sulfur content in the gasoline decreases. 85ppm ₀ To 40 ~ 125ppm, the nitrogen content is reduced to 0. 4-0. 85ppm ₀

Example 2

This embodiment illustrates a case where the method of the first solution provided by the present invention is used to catalytically convert gasoline with different olefin content in a small fluidized bed reactor to reduce gasoline olefins.

The four gasolines listed in Table 2 were used as raw materials, and the catalyst A listed in Table 1 was used. Its carbon deposit was 0.05% by weight. The catalytic conversion of gasoline was reduced in a small fluidized bed reactor with continuous reaction regeneration operation. Olefin test. The specific test procedure is the same as in Example 1.

The test conditions, test results, and properties of gasoline are listed in Table 4. It can be seen from Table 4 that after catalytic conversion of gasoline with different olefin content, the isomeric fluorenes in the gasoline composition account for 22.26 ~ 64.8% by weight, and the aromatic hydrocarbons account for 6.5 ~ 55.1% by weight. 4〜1. 6ppm。 It accounts for 3.9 ~ 16.3% by weight, the sulfur content in gasoline is reduced to 40 ~ 578ppm, and the nitrogen content is reduced to 0.4 ~ 1. 6ppm. The higher the olefin content of gasoline, the higher the isomeric hydrocarbon content in the composition of the gasoline.

Example 3

This embodiment illustrates a case where the method of the first solution provided by the present invention is adopted, and gasoline feedstocks are used in different operating conditions to catalytically convert gasoline gasoline to reduce olefins in a small-scale fluidized bed reactor.

The gasoline A listed in Table 2 is used as a raw material, and the catalyst A listed in Table 1 is used, and the carbon deposit is 0.05% by weight. The catalytic conversion of gasoline in a small fluidized bed reactor for continuous reaction regeneration operation is performed to reduce olefins. test. The main operating conditions are: the reaction temperature is 250 to 450 ° C, the pressure at the top of the reactor is 0.2 MPa, the weight hourly space velocity is 4 to 10 hours-the agent to oil ratio is 3 to 8, and the water to oil ratio is 0.03 to 0. 05. The specific test procedure is the same as in Example 1. The test conditions, test results, and properties of gasoline are listed in Table 5.

It can be seen from Table 5 that different operating conditions have different degrees of influence on the catalytic conversion of gasoline feedstock. Isoparaffins in the gasoline composition account for 52.8 to 56.8% by weight, and aromatics account for 25.0 to 26.5% by weight. 41ppm ₀实施例 4 Example olefin only accounted for 6. 0-9. 3% by weight, the sulfur content in gasoline was reduced to 36 ~ 46ppm, and the nitrogen content was reduced to 0.3 ~ 0. 41ppm ₀ EXAMPLE 4

This example illustrates that by adopting the method of the first solution provided by the present invention, olefin-rich gasoline is Catalytic conversion on a riser catalytic cracker reduces gasoline olefins. The test results were used to simulate a gasoline riser in a dual riser reactor.

Using gasoline A listed in Table 2 as a raw material, and using catalyst C listed in Table 1, the carbon deposit is 0.05% by weight. The catalytic conversion of gasoline is reduced on a medium-sized riser catalytic cracking unit operated by continuous reaction regeneration. Testing of olefin, sulfur and nitrogen content. The gasoline feedstock was mixed with high-temperature water vapor and entered the bottom of the riser. The reaction conditions were as follows: The reaction temperature was 550 ° C, the pressure at the top of the reactor was 0.2 MPa, and the weight hourly space velocity was 50. 03。 Hour-agent oil ratio is 6, water oil ratio is 0.03. The reaction product, steam and the catalyst to be produced are separated in a settler, and the reaction product is separated to obtain a gas product and a liquid product. The catalyst to be produced enters the stripper, and the hydrocarbon products adsorbed on the catalyst to be produced are extracted by water vapor. The stripped catalyst enters the regenerator and is brought into contact with the heated hot air for regeneration. After the regenerated catalyst is cooled, it is returned to the reactor for recycling. The test conditions and test results are listed in Table 6, and the properties of gasoline are listed in Table 7.

As can be seen from Table 6, the liquefied gas yield was 14.60% by weight, of which propylene was 3.83% by weight; isobutane was 5.58% by weight, and the dry gas yield was only 0.66% by weight. It can be seen from Table 7 that the isofluorene content of gasoline is 40.32% by weight, the aromatics are 30.86% by weight, and the olefins are only 16.49% by weight. The sulfur content in gasoline is reduced to 97ppm, and the nitrogen content Reduced to 0.76ppm.

Example 5

This embodiment illustrates that by adopting the method of the first solution provided by the present invention, olefin-rich gasoline is cut into a light gasoline fraction and a heavy gasoline fraction, and these two gasoline fractions are respectively entered from the bottom and middle and upper parts of a medium riser reactor to perform Test of catalytic conversion to reduce gasoline olefins, sulfur and nitrogen.

The light gasoline fraction C and the heavy gasoline fraction D listed in Table 2 were used as raw materials, and the catalyst A listed in Table 1 was used, whose carbon deposit was 0.05% by weight, and the medium riser catalytic cracking described in Example 4 was used. A gasoline catalytic conversion test is performed on the device. Light gasoline fraction C is mixed with high-temperature water vapor and enters the bottom of the riser, and is contacted with a regeneration catalyst at a temperature of 30 ° C for catalytic conversion reaction. At the same time, heavy gasoline fraction D enters the middle of the riser and is contacted with a catalyst at a temperature of 400 ° C. Catalytic conversion reaction; the remaining test steps are the same as in Example 4. The reaction conditions are: the pressure at the top of the reactor is 0.2 MPa, the weight hourly space velocity is 50 ~ 100 hours — the weight ratio of catalyst to gasoline raw material is 6, water vapor The weight ratio to gasoline raw materials is 0.03. Test conditions and test results are shown in Table 6, and gasoline properties are shown in Table 7.

As can be seen from Table 6, the gas yield was 6.99% by weight, the diesel yield was 4.53% by weight, and the gasoline yield was 86.78% by weight. It can be seen from Table 7 that the isoparaffins in the gasoline composition account for 51.25% by weight, the aromatics account for 26.98% by weight, and the olefins account for only 8.59% by weight. The sulfur content in gasoline has been reduced to 786ppm, and the nitrogen content has been reduced. To 0.65ppm ₀

Example 6 This embodiment illustrates a case where the method of the first solution provided by the present invention is adopted to reduce gasoline olefins by using different reaction temperatures and catalytic conversion of water-oil ratio in a small fluidized bed reactor.

The gasoline C listed in Table 2 was used as the raw material, and the catalyst A listed in Table 1 was used, and the carbon deposit was 0.05% by weight. The gasoline catalytic conversion test was performed in a small-scale fluidized bed reactor with continuous reaction regeneration operation. The main operating conditions of this test are as follows: the reaction temperature is 150 ~ 300 ° C, the pressure at the top of the reactor is 0.2 MPa, the weight hourly space velocity is 4 hours-the agent-oil ratio is 6, the water-oil ratio is 0 ~ 0. 03 . The test conditions, test results and the properties of gasoline are listed in Table 8.

As can be seen from Table 8, the isoparaffins in the gasoline composition account for 61.2 to 65.1% by weight, aromatics account for 6.5 to 6.7% by weight, and olefins account for only 16.0 to 19.5% by weight, 10-1。 The sulfur content in gasoline was reduced to 101.3 ~ 137. 2ppm, and the nitrogen content was reduced to 0.65-1. 10ppm.

Example 7

This example illustrates: (1) Using the method of the second solution provided by the present invention and using different types of catalysts to carry out the reaction in a small-scale fluidized bed reactor can significantly reduce the olefin content and sulfur and nitrogen content of the gasoline fraction.

Using gasoline fraction A listed in Table 2 as a raw material, four different types of catalysts listed in Table 1 were used to perform a catalytic conversion test of gasoline fractions in a small-scale fluidized bed reactor of continuous reaction-regeneration operation. Gasoline fraction A is mixed with high-temperature water vapor and enters a fluidized-bed reactor. The reaction temperature is 450 ° C, the pressure at the top of the reactor is 0.2 MPa, and the weight hourly space velocity is 10 hours. The agent-oil ratio is 3, and the water-oil ratio The catalyst was contacted and reacted under the condition of 0.03. The reaction product, steam and the catalyst to be grown are separated in a settler; the reaction product is further separated to obtain gas, gasoline and diesel; and the catalyst to be grown enters the stripper, and the hydrocarbon products adsorbed on the catalyst to be grown are taken out by steam; steam 3 重 y。 The extracted catalyst enters the regenerator and is incompletely regenerated in contact with the heated air to obtain a carbon deposit of 0.3 heavy y. The incompletely regenerated catalyst is cooled and returned to the reactor for recycling. The main operating conditions of the test, product distribution and the properties of the product gasoline are listed in Table 9.

It can be seen from Table 9 that different types of catalysts have a certain effect on the results of the catalytic conversion reaction of gasoline fractions; in the gasoline products after the reaction, isoparaffins account for 43.2 to 49.7 wt%, and aromatics account for 26.0. -28. 9% by weight, olefins only account for 11.9 ~ 20.5% by weight, the sulfur content in gasoline is reduced to 45 ~: L 32ppm, the nitrogen content is reduced to 0.4 ~ 1. Oppm; The reaction effect is the best, and the gasoline product has the lowest olefin content, sulfur and nitrogen content.

Example 8

This example illustrates that: gasoline fractions with different olefin contents can be used as the feedstock of the method provided in the second solution of the present invention; the reaction in a small fluidized bed reactor can significantly reduce the olefin content, sulfur, and nitrogen contents of the gasoline fraction.

The four gasoline fractions listed in Table 2 were used as raw materials. Catalyst A listed in Table 1 was used. Tests were performed in a small fluidized bed reactor for reaction-regeneration operation. The specific test procedure is the same as in Example 7. The main operating conditions of the test, the product distribution and the properties of the product gasoline are listed in Table 10.

It can be seen from Table 10 that after catalytic conversion reactions of gasoline fractions with different olefin contents, isoparaffins in gasoline products account for 21.6 to 58.2% by weight, aromatics account for 7.2 to 58.2% by weight, olefins. Oppm。 Accounted for 4. 0 ~ 22.5 wt%, while the sulfur content dropped to 45 ~ 780ppm, the nitrogen content dropped to 0.4 ~ 3. Oppm. Therefore, gasoline fractions with higher olefin content are also suitable for the method provided by the present invention, and the content of isoparaffin in the gasoline product is higher.

Example 9

This example illustrates that the same gasoline fraction can be reacted under different operating conditions by applying the method provided in the second solution of the present invention. The gasoline product has slightly different olefin content, sulfur, and nitrogen content.

The gasoline conversion fraction A listed in Table 2 was used as a raw material, and the catalyst A listed in Table 1 was used to perform a catalytic conversion test in a small-scale fluidized bed reactor of continuous reaction-regeneration operation. The main operating conditions are as follows: the reaction temperature is 350 ~ 550 ° C, the pressure at the top of the reactor is 0.2 MPa, the weight hourly space velocity is 4 ~ 20 hours-the agent-oil ratio is 2-6, and the water-oil ratio is 0.03 ~ 0. 05. The specific test procedure is the same as in Example 7. The main operating conditions of the test, the product distribution, and the properties of the product gasoline are listed in Table 11.

It can be seen from Table 11 that different reaction conditions have a certain effect on the catalytic conversion reaction of gasoline fractions; the isoparaffins in the gasoline products account for 47.0 to 52.8% by weight, and the aromatics account for 25.1 to 29. 40ppm。 0% by weight, olefins only account for 9.8 ~ 12.3% by weight; and the sulfur content in gasoline products is reduced to 35 ~ 45ppm, the gas content is reduced to 0.3-0. 40ppm.

Example 10

This embodiment illustrates: (1) Using the method provided in the second solution of the present invention, gasoline fractions react with catalysts with different carbon deposits in a small fluidized bed reactor, and the olefin content, sulfur content, and gas content of gasoline products are slightly different.

Using gasoline A listed in Table 2 as a raw material, catalyst A listed in Table 1 was used to perform a gasoline fraction catalytic conversion test in a small-scale fluidized bed reactor of continuous reaction-regeneration operation. The main operating conditions are as follows: the reaction temperature is 450 ~ 600 ° C, the pressure at the top of the reactor is 0.2 MPa, the weight hourly space velocity is 10 hours- ² , the agent-oil ratio is 3, and the water-oil ratio is 0.03. The specific test procedure is basically the same as in Example 7. The main operating conditions of the test, the product distribution, and the properties of the product gasoline are listed in Table 12.

It can be seen from Table 12 that catalysts with different carbon deposits react with the same gasoline fraction under the same reaction conditions, and the olefin content, sulfur and gas content of their gasoline products are slightly different. The isopyrene hydrocarbons in its gasoline products accounted for 43.6 to 50.1% by weight, aromatics accounted for 25.0 to 31.5% by weight, and olefins accounted for only 11.0 to 18.6% by weight, and the sulfur content decreased to 3〜0 · 6ppm。 36 ~ 60ppm, nitrogen content dropped to 0.3 ~ 0.6 ppm.

Example 11

This embodiment illustrates: The method provided by the third solution of the present invention is applicable to many different types of cracking catalysts. Agent.

Using gasoline fraction A listed in Table 2 as a raw material, four different types of catalysts listed in Table 1 were used to conduct a gasoline catalytic conversion test in a small fluidized bed reactor. In order to well simulate the method provided by the present invention, the catalysts used in the tests were all coke-accumulated catalysts that had undergone conventional catalytic cracking reactions, and the amount of coke deposited on the catalysts was 1.1% by weight.

The main test steps are as follows: Gasoline fraction A is mixed with high-temperature water vapor and enters the fluidized-bed reactor. At a reaction temperature of 450 ° C, the pressure at the top of the reactor is 0.2 MPa, the weight hourly space velocity is ^-1 , and the agent-oil ratio is 8. The catalyst is brought into contact with the catalyst under the condition of water-oil ratio of 0.10 to perform a catalytic conversion reaction. The reaction product and water vapor are introduced into the subsequent separation system from the top of the reactor, and further separated into products such as dry gas, liquefied gas, gasoline, diesel, and the yield of each product is calculated. After the reaction, the charcoal-containing catalyst is stripped with steam, and then heated with oxygen to be burned to regenerate it. Collect and meter the regenerated flue gas, analyze its composition, and use it to calculate the coke yield.

The main operating conditions of the test, the product distribution, and the properties of the product gasoline are listed in Table 13. As can be seen from Table 1 3, after gasoline fraction A undergoes the above-mentioned reaction, the isofluorene hydrocarbons in the family composition of the product gasoline account for 35.1 to 48.4% by weight, and the aromatic hydrocarbons account for 26.2 to 30.9% by weight, 5〜1. 2ppm。 Olefins only accounted for 13.4 ~ 22.3% by weight; meanwhile, the sulfur content dropped to 44 ~ 152ppm, and the nitrogen content dropped to 0.5 ~ 1. 2ppm. Therefore, although using different types of catalysts will cause the reaction results to be slightly different, the olefin content, sulfur and nitrogen content of gasoline fractions are significantly reduced.

Example 12

This embodiment illustrates that the method provided by the third solution of the present invention can be used to treat inferior gasoline with different olefins, sulfur, and nitrogen contents.

The four gasolines listed in Table 2 were used as raw materials, and the catalyst A listed in Table 1 was used to conduct a gasoline catalytic conversion test in a small fluidized bed reactor. The main reaction conditions are as follows: the reaction temperature is 450 ° C, the pressure at the top of the reactor is 0.2 MPa, the weight hourly space velocity is 4 h, and the oil ratio of ¹ agent is 8: 1, 7 and the oil ratio is 0.1: 10, the catalyst used in the test The carbon deposition amount of A was 1.1% by weight. The main test steps are the same as in Example 11.

The main operating conditions of the test, the product distribution, and the properties of the product gasoline are listed in Table 14. It can be seen from Table 14 that after the above reactions of four gasoline fractions of different properties, the isoparaffins in the family composition of the product gasoline accounted for 24.3 to 48.4% by weight, and the aromatics accounted for 8.2 to 56.8% by weight. 5〜5. 0ppm。%, olefins only accounted for 4.8 ~ 25.9% by weight; At the same time, the sulfur content dropped to 44 ~ 678ppm, the gas content dropped to 0.5 ~ 5. 0ppm. Therefore, although the use of gasoline fractions with different properties will slightly affect the reaction results, the olefins, sulfur, and nitrogen contents in gasoline have been significantly reduced, and the iso-fluorenes obtained after gasoline tests with higher olefin contents The content is also higher.

Example 1 3 This example illustrates: (1) Using the method provided by the third solution of the present invention, the quality of gasoline can be significantly improved within the reaction condition range of the present invention.

The gasoline A listed in Table 2 was used as a raw material, and the catalyst A listed in Table 1 was used to conduct a gasoline catalytic conversion test in a small fluidized bed reactor. The main reaction conditions are as follows: the reaction temperature is 400 ~ 520 ° C, the pressure at the top of the reactor is 0.2 Mpa, the weight hourly space velocity is 4 ~ 15h- the ratio of agent to oil is 6-12: the ratio of water to oil is 0.1 to 0. 15 : 1. The amount of carbon deposited by the catalyst A used in the test was 1.1% by weight. The main test steps are the same as in Example 11.

The main operating conditions of the test, the product distribution and the properties of the product gasoline are listed in Table 15. It can be seen from Table 15 that different reaction conditions slightly affect the test results. In the family composition of product gasoline, isomeric fluorenes account for 41.1 to 48.4% by weight, aromatics account for 26.2 to 31.4% by weight, and olefins account for only 12.3 to 15.6% by weight; with this At the same time, the sulfur content is reduced to 40 ~ 56ppm, and the gas content is reduced to 0.5 ~ 0. 6ppm.

Example 14

This embodiment illustrates: (1) Using the method provided in the third solution of the present invention, the quality of gasoline can be significantly improved within the range of the catalyst coke amount according to the present invention.

Taking gasoline A listed in Table 2 as the raw material oil and using catalyst A listed in Table 1, the carbon deposits were 0.9% by weight, 1.1% by weight and 1.3% by weight, respectively, in a small fluidized bed A catalytic conversion test of gasoline was performed in the reactor. The main reaction conditions are as follows: The reaction temperature is 450 ° C. C. The pressure at the top of the reactor is 0.2 Mpa, the weight hourly space velocity is ^-1 , the agent-oil ratio is 8: 1, and the oil ratio is 0.10: 1. The main test procedure is the same as in Example 11.

The main operating conditions of the test, product distribution and the properties of the product gasoline are listed in Table 16. It can be seen from Table 16 that the use of catalysts with different carbon deposits has a slight effect on the test results. In the family composition of product gasoline, isoparaffins account for 41.2 to 49.4% by weight, aromatics account for 25.8 to 27.1% by weight, and olefins account for only 11.3 to 20.3% by weight; meanwhile, , Sulfur content decreased to 40 ~ 56ppm, nitrogen content decreased to 0.3 · 0.5ppm.

Example 15

This embodiment illustrates that: injecting the gasoline fraction into the stripping section according to the injection position provided in the third solution of the present invention can not only achieve the catalytic conversion of the gasoline fraction but also ensure a good stripping effect.

On a medium riser catalytic cracking unit, Catalyst A in Table 1 was used for the catalytic conversion test of gasoline. The pre-heated conventional catalytic cracking feedstock with a density of 856 kg / ^m3 was injected into the riser reactor, and contacted with the high-temperature catalyst A from the regenerator, and then vaporized and reacted. The mixture of reaction oil, gas and catalyst enters the settler through the riser. The coked catalyst from the conventional catalytic cracking reaction process described above falls into the settler stripping section. The injection position of the gasoline fraction A in Table 2 after preheating is as follows: (1) It is injected and reacted at 40% of the height of the dense phase bed of the catalyst in the stripping section, that is, the injection port h shown in FIG. 12. (2) It is injected and reacted at 65% of the height of the dense phase bed of the catalyst in the stripping section, that is, The injection port g is shown in FIG. 12. The catalyst in the stripping section gradually moves to the middle and lower part of the stripping section under the effect of the pressure balance of the reaction-regeneration system. Under the action of stripping steam, the catalyst contacts the steam in countercurrent to replace the reactive oil and gas adsorbed in the catalyst pores and between the catalyst particles. The reaction product of the gasoline fraction A and the reaction product of the conventional catalytic cracking are introduced into the subsequent separation system from the top of the settler for product separation. The green catalyst that has completed the above-mentioned stripping process is sent to the regenerator for scorch regeneration through the green tube. The regenerated catalyst is returned to the reaction system, and firstly reacts with conventional catalytic cracking raw materials. The coke-accumulated catalyst after the reaction falls into the settler stripping section for recycling.

The main operating conditions of the test, the product distribution, and the properties of the product gasoline are listed in Table 17. It can be seen from Table 17 that different injection positions of gasoline fractions have certain influence on the product distribution and product properties of the gasoline fraction catalytic conversion test. When the injection port g is used, the gasoline yield is 81.55% by weight, and the contents of olefins, aromatics, and isoparaffins in the gasoline products are 11.6% by weight, 27.1% by weight, and 49.1% by weight. , The content of hydrogen in coke was 10.14% by weight; and when the injection port h was used, the yield of gasoline was 84.07% by weight, and the contents of olefins, aromatics, and isomerized fluorene in gasoline products were 14.4 weights. %, 26.8% by weight, and 46.3% by weight, the hydrogen content in coke is 8.34%. Therefore, the gasoline fraction is injected into the stripping section from the position provided by the third solution of the present invention, and the gasoline fraction can be achieved. Catalytic conversion can also ensure good stripping effect.

Table 1

Catalyst number A B C D Trade name CRC-1 RHZ-200 ZCM-7 RAG-1 Zeolite type REY REHY USY REY-USY-ZRP Chemical composition, weight%

Alumina 26. 5 33. 0 46. 4 44. 6 Sodium oxide 0. 19 ″ 0. 29 0. 22 0. 13 Iron oxide 0.09 1. 1 0. 32 1 Apparent density, kg / m ³ 450 560 690 620 Pore volume, ml / g 0.41 0. 25 0. 38 0. 36 Specific surface area, mV g 132 92 164 232 Wear index, weight% 4 4. 2 3. 2 / 2. 5 Screening Composition, weight ° /.

0-40 microns 7. 3 15. 2 4. 8 13. 1

40-80 micron 43. 7 55. 1 47. 9 54. 9

> 80 microns 49. 0 29. 7 47. 3 32. 0 micro-reactive MA 70 68 69 66

Table 2

Gasoline material number ABCD Density (2 (TC), kg / m ³ 743. 0 727. 1 653. 1 786. 4 Octane number

RON 91. 3 92. 1 93. 2 88. 6

M0N 79. 5 79. 8 81. 5 78. 4 Sulfur, ppm 200 2035. 5 376. 7 2892. 2 Nitrogen, ppm 30 151. 3 14. 3 93.0 Carbon, heavy. /. 86. 80 86. 54 85. 26 86. 29 Hydrogen, weight% 13. 03 13. 26 14. 52 12. 99 Distillation range, ° C

Initial boiling point 49 44 44 90

10% 63 59 48 91

30% 82 78 53 120

50% 106 104 60 153

70% 140 133 65 173

90% 176 166 75 186 Final boiling point 195 200 90 202 Family composition, weight%

29. 6 26. 9 19. 0 25. 0 Normal fluorene 5. 3 4. 9 5. 0 5. 1 Isomer fluorene 25.3 22. 0 14. 0 19. 9 Cycloalkane 8. 3 7 2 5. 2 12. 3 Alkenes 37.8 47. 6 69. 6 13. 6 Aromatics 24. 3 18. 3 6. 2 49. 1 table 3

Catalyst ABCD Catalyst carbon deposition,% by weight 0. 05 0. 05 0. 05 0. 05 Reaction temperature, ° c 300 300 300 300 Weight hourly space velocity, hour — ¹ 4 4 4 4 agent oil ratio 6 6 6 6 water oil Compared with 0.03 0. 03 0. 03 0. 03 product distribution, weight ° /.

Dry gas 1. 36 0. 87 0. 65 0. 56 Liquefied gas 3. 87 4. 69 4. 76 4. 93 Gasoline 85. 97 86. 85 88. 70 89. 95 Light diesel 4. 37 3. 98 3 01 2. 36 Heavy diesel 2.43 2. 02 1. 63 1. 23 Coke 1. 98 1. 56 1. 23 0. 93 Loss 0.02 0. 03 0. 02 0. 04 Gasoline properties Raw material properties

RON 91. 3 88. 2 89. 3 90. 2 90. 5

M0N 79. 5 80. 1 80. 0 79. 8 79. 8 Sulfur, pm 200 40 65 102 125 Nitrogen, ppm 30 0. 4 0. 7 0. 76 0. 85 Aromatics,% 24. 32 25. 20 25. 00 25. 30 26. 56 Alkenes,% 37. 79 8. 70 10. 87 14. 98 18. 39 Alkane,% 29. 64 59. 01 56. 92 52. 29 47. 19 Normal Alkanes 5. 29 5. 01 5. 05 4. 98 4. 86 Isomers 25. 35 54. 0 51. 87 47. 31 42. 33

8. 25 7. 09 7. 21 7. 43 7. 86 Table 4

Feed oil ABCD reaction temperature,. c 300 300 300 400 Weight hourly space velocity, hour — ¹ 4 4 4 4 Agent oil ratio 6 6 6 6 Water oil ratio 0.03 0. 03 0. 03 0. 03 Product distribution, weight%

Dry gas 1. 36 1. 57 0. 73 1. 33 Liquefied gas 3. 87 4. 64 6. 05 7. 14 Gasoline 85. 97 84. 11 86. 39 81. 83 Light diesel 4. 37 5. 04 3 33 4. 32 Heavy diesel 2.43 2. 61 1. 36 2. 04 Coke 1. 98 2. 02 2. 12 3. 14 Loss 0.02 0. 01 0. 02 0. 20 Gasoline properties

RON 88. 2 90. 8 90. 2 89. 4

M0N 80. 1 81. 0 81. 2 78. 6 Sulfur, pm 40 402 108. 5 578 Nitrogen, pm 0. 4 1. 0 0. 83 1. 6 Aromatics,% 25. 20 19. 20 6. 52 55. 18 Alkenes,% by weight 8. 70 10. 92 16. 34 3. 89 Alkanes,% by weight 59. 01 62. 72 70. 02 27. 48 Normal alkanes 5. 01 4. 95 5. 20 5. 22 Isoparaffins 54.0 57. 77 64. 82 22. 26

7. 09 7. 16 7. 12 13. 45

Operating conditions

Reaction temperature, ° c 300 300 300 300 250 450 weight hourly space velocity, hour ¹ 8 4 4 4-4 10 agent oil ratio 3 6 8 6 6 6 water oil ratio 0.03 0. 03 0. 03 0. 05 0 03 0. 05 Product distribution, weight ° /.

Dry gas 1. 12 1. 36 1. 56 1. 13 0. 56 3. 41 Liquefied gas 3. 55 3. 87 4. 32 3. 53 1. 87 5. 48 Gasoline 87. 11 85. 97 84. 54 86. 61 87. 02 82. 79 Light diesel 4. 01 4. 37 4. 63 4. 18 5. 47 3. 24 Heavy diesel 2. 11 2. 43 2. 75 2. 33 2. 86 1. 86 Coke 1. 86 1. 98 2. 02 1. 95 1. 96 2. 93 Loss 0.24 0. 02 0. 18 0. 27 0. 26 0. 29 Gasoline properties Raw material properties

RON 91. 3 89. 0 88. 2 87. 8 89. 0 87. 6 88. 8

M0N 79. 5 80. 0 80. 1 80. 1 79. 9 80. 0 80. 0 sulfur, pm 200 46 40 36 42 36 36 nitrogen, pm 30 0. 41 0. 4 0. 3 0. 4 0. 3 0. 3 Aromatics, weight ° /. 24. 32 25. 12 25. 20 26. 45 25. 03 26. 02 Alkenes,% 37. 79 9. 32 8. 70 6. 67 9. 13 5. 98 9. 09 Alkanes,% 29. 64 58. 45 59. 01 59. 80 58. 76 61. 84 57. 80 Normal paraffin 5. 29 5. 07 5. 01 5. 11 5. 07 5. 03 4. 98 Isoparaffin 25. 35 53. 38 54. 0 54. 69 53. 69 56. 81 52. 82

8. 25 7. 11 7. 09 7. 08 7. 10 7. 15 7. 09

Table 6

*: The value before "/" indicates the reaction condition at the bottom of the gasoline riser, and the value after "/" indicates the reaction condition at the middle of the gasoline riser.

Table Ί

Raw material A Example 4 Raw material C Raw material D Example 5 Density (20 ° C), kg / m ³ 743. 0 741. 8 653. 1 786. 4 746. 7 Sin value

RON 91. 3 90. 0 93. 2 88. 6 91. 0

M0N 79. 5 80. 8 81. 5 78. 4 81.2 Sulfur, ppm 200 97 376. 7 2892. 2 786 Nitrogen, Ppm 30 0. 76 14. 3 93. 0 0. 65 carbon, weight% 86. 80 86. 71 85. 26 86. 29 86. 43 Hydrogen,% by weight 13. 03 13. 22 14. 52 12. 99 13. 42 Distillation range, ° c

Initial boiling point 49 49 44 90 46

10% 63 75 48 91 72

30% 82 98 53 120 90

50% 106 120 60 153 118

70% 140 147 65 173 143

90% 176 178 75 186 175 Final boiling point 195 202 90 202 196 Family composition, weight%

Aromatics 24. 32 30. 86 6. 15 49. 08 26. 98 Alkenes 37. 79 16. 49 69. 64 13. 62 8. 59 Alkanes 29. 64 45. 34 19. 04 25. 00 56. 57 Normal Alkanes 5. 29 5. 02 4. 98 5. 12 5. 32 Isomers 25. 35 40. 32 14. 06 19. 88 51. 25 Cycloalkanes 8. 25 7. 31 5. 17 12. 30 7. 86 Table 8

Operating conditions

Reaction temperature, 150 200 250 300 weight hourly space velocity, hour — ¹ 4 4 4 4 agent oil ratio 6 6 6 6 water oil ratio 0 0. 02 0. 02 0. 03 product distribution, weight%

Dry gas 0. 86 0. 51 0. 64 0. 73 Liquefied gas 2. 04 2. 68 4. 30 6. 05 Gasoline 93. 24 93. 23 90. 02 86. 39 Light diesel 1. 65 1. 52 2 46 3. 33 Heavy Diesel 0.76 0. 73 1. 09 1. 36 Coke 1. 33 1. 30 1. 40 2. 12 Loss 0.12 0. 03 0. 09 0. 02 Gasoline properties Raw material properties

RON 93. 2 88. 2 89. 8 90. 0 90. 2

M0N 81. 5 81. 2 81. 5 81. 5 81. 5 Sulfur, ppm 376. 7 1 06. 5 1 37. 2 1 01. 3 1 08. 5 Nitrogen, pm 14. 3 0. 65 1. 1 0 0. 65 0. 83 Aromatics,% by weight 6. 15 6. 55 6. 66 6. 50 6. 52 Alkenes,% by weight 69. 64 16. 70 19. 53 15. 98 16. 34

19. 04 68. 74 66. 49 70. 30 70. 02 Normal paraffin 4. 98 5. 30 5. 33 5. 17 5. 20 Isoparaffin 14. 06 63. 44 61. 16 65. 1 3 64 82 Cyclopsene, weight% 5. 17 8. 01 7. 32 7. 22 7. 12

Table 9

Catalyst ABCD Catalyst carbon deposition, weight% 0.3 0.3 0.3 0.3 reaction temperature, ° c 450 450 450 450 weight hourly space velocity, hour 1 ¹ 10 10 10 10 agent oil ratio 3 3 3 3 water oil ratio 0.03 0.03 0.03 0.03 product distribution, weight%

Dry gas 0.93 0.79 0.64 0.42 Liquefied gas 5.66 6.09 6.35 6.79 Gasoline 84.75 85.65 86.32 87.02 Light diesel 4.64 4.15 3.65 3.04 Heavy diesel 1.41 1.12 1.06 0.98 Coke 2.55 2.20 1.98 1.75 Loss

Properties of gasoline

RON 91.3 88.4 89.4 90.0 90.2

M0N 79.5 80.0 80.0 79.9 79.7 Sulfur, pm 200 45 102 74 132 Nitrogen, Ppm 30 0.4 0.7 0.8 1.0 Aromatics, weight% 24.3 26.0 26.4 27.0 28.9 Olefins, weight% 37.8 11.9 13.4 16.8 20.5 Tritene hydrocarbons, weight% 29.6 54.9 52.9 49.0 48.2 48.2 Normal fluorene 5.3 5.2 5.1 5.0 5.0 Isomerized fluorene 25.3 49.7 47.8 44.0 43.2 Cyclopentene, weight% 8.3 7.2 7.3 7.2 7.4 Table 10

The amount of carbon deposits in the feedstock, oil ABCD catalyst A, weight% 0.3 3 0.3 0.3 0.3 reaction temperature,. c 450 450 450 450 Weight hourly space velocity, hour — ¹ 10 10 10 10 Agent oil ratio 3 3 3 3 Water oil ratio 0.03 0. 03 0. 03 0. 03 Product distribution, weight ° /.

Dry gas 0.93 1. 08 0. 52 1. 11 Liquefied gas 5. 66 6. 06 6. 14 6. 86

84. 75 83. 25 86. 41 81. 71 Light diesel 4.64 5. 13 3. 53 5. 35 Heavy diesel 1. 41 1. 56 0. 90 1. 98 Coke 2. 55 2. 85 2. 45 2. 98 Loss 0.06 0. 07 0. 05 0. 01 Gasoline properties

RON 88. 4 90. 5 89. 6 90. 0

M0N 80. 0 80. 5 80. 5 79. 0 Sulfur, pm 45 150. 6 56 780 Nitrogen, ppm 0. 4 2. 0 1. 50 3. 0 Aromatics, weight ° /. 26. 0 21. 3 7. 20 58.2 Alkenes,% by weight 11. 9 15. 7 22. 5 4. 0 Alkanes,% by weight 54. 9 56. 0 63. 4 26. 6 Normal alkanes 5.2 4. 8 5. 2 5. 0 Heterofluorene 49.7 51. 2 58. 2 21. 6

7. 2 7. 0 6. 9 11. 2 Table 11

Catalyst A carbon deposition,% by weight 0. 3 0. 3 0. 3 0. 3 0. 3 Operating conditions

Reaction temperature, ° c. 450 450 450 350 550 Weight hourly space velocity, hour — ¹ 4 10 10 10 20 Agent oil ratio 2 3 6 3 3 Water oil ratio 0.03 0. 03 0. 03 0. 03 0. 05 Products Distribution, weight%

Dry gas 0.96 0. 93 1. 02 0. 61 2. 56 Liquefied gas 6. 23 5. 66 7. 55 3. 64 7. 89 Gasoline 83. 65 84. 75 82. 00 86. 15 81. 26 Light diesel 4.76 4. 64 4. 75 5. 23 4. 21 Heavy diesel 1.50 1. 41 1. 66 1. 87 1. 20 Coke 2. 65 2. 55 2. 98 2. 45 2. 86 Loss 0.05 0. 06 0. 04 0. 05 0. 02 Gasoline properties Raw material properties

RON 91. 3 88. 6 88. 4 88. 0 87. 8 89. 2

M0N 79. 5 80. 1 80. 0 80. 0 80. 1 80. 0 Sulfur, pm 200 40 45 40 35 35 Nitrogen, ppm 30 0. 3 0. 4 0. 4 0. 3 0. 3 Aromatics, heavy % 24. 3 28. 2 26. 0 27. 6 25. 1 29. 0 Olefins,% 37. 8 11. 6 11. 9 10. 5 9. 8 12. 3 Alkane,% 29. 6 53 3 54. 9 54. 8 57. 9 51. 9 normal paraffin 5. 3 5. 2 5. 2 5. 0 5. 1 4. 9 isomeric fluorene 25. 3 48. 1 49. 7 49. 8 52. 8 47. 0 Cyclopentene, weight% 8. 3 6. 9 7. 2 7. 1 7. 2 6. 8 Table 12

Catalyst A carbon deposit,% by weight 0.45 0. 30 0. 25 0. 15 Operating conditions

Reaction temperature, ° c 450 450 450 600 weight hourly space velocity, hour — ¹ 10 10 10 30 agent oil ratio 3 3 3 3 water oil ratio 0.03 0. 03 0. 03 0. 05 product distribution, weight%

Dry gas 0.63 0. 93 0. 96 2. 88 Liquefied gas 5. 03 5. 66 5. 93 10. 43 Gasoline 87. 60 84. 75 84. 15 78. 50 Light diesel 3. 46 4. 64 4 73 3. 98 Heavy diesel 1.13 1. 41 1. 52 1. 20 Coke 2. 11 2. 55 2. 63 2. 96 Loss 0.04 0. 06 0. 08 0. 05 Gasoline properties Raw material properties

RON 91. 3 89. 6 88. 4 88. 2 90. 2

M0N 79. 5 79. 5 80. 0 80. 0 80. 0 Sulfur, pm 200 60 45 40 36 gas, Ppm 30 0. 6 0. 4 0. 4 0. 3 aromatic hydrocarbons, weight% 24. 3 25. 0 26. 0 26. 7 31.5 Alkenes,% by weight 37. 8 18. 6 11. 9 11. 0 12. 1 Alkane,% by weight 29. 6 48. 8 54. 9 55. 2 49. 7 Normal Alkanes 5. 3 5. 2 5. 2 5. 1 4. 8 Isoparaffins 25. 3 43. 6 49. 7 50. 1 44. 9

8. 2 7. 6 7. 2 7. 1 6. 7 Table 13

Catalyst ABCD Catalyst carbon deposit, weight "/. 1. 1 1. 1 1. 1 1. 1 reaction temperature, ° c 450 450 450 450 hourly hourly space velocity, hour 1 ¹ 4 4 4 4 agent oil ratio 8 8 8 8 Water-oil ratio 0. 1 0. 1 0. 1 0. 1 Product distribution, weight%

Dry gas 0.98 0. 81 0. 76 0. 87 Liquefied gas 7.74 7. 98 9. 01 11. 76 Gasoline 84. 00 84. 65 84. 36 82. 48 Light diesel 4. 06 3. 84 3 36 2. 76 Heavy diesel 1.32 1. 21 1. 16 1. 01 Coke 1. 86 1. 46 1. 32 1. 07 Loss 0.04 0. 05 0. 03 0. 05 Gasoline properties Raw material properties

RON 91. 3 88. 2 89. 0 90. 1 90. 4

M0N 79. 5 80. 0 80. 0 79. 8 79. 3 Rau, ppm 200 44 76 112 152 gas, Ppm 30 0. 5 0. 8 0. 9 1. 2 aromatic hydrocarbons, weight% 24. 3 26.2 26. 5 28. 5 30. 9 olefins, weight ° /. 37.8 13. 4 15. 3 17. 6 22. 3 Alkanes,% by weight 29. 6 53. 4 51. 1 47. 1 40. 1 Normal alkanes 5. 3 5. 0 5. 1 5. 0 5 0 Isoparaffins 25. 3 48. 4 46. 0 42. 1 35. 1 Cycloalkane,% by weight 8. 3 7. 0 7. 1 6. 8 6. 7 Table 14

Feed oil ABCD Catalyst A carbon deposit,% by weight 1. 1 1. 1 1. 1 1. 1 Reaction temperature, ° c 450 450 450 450 Weight hourly space velocity, hour — ¹ 4 4 4 4 Agent oil ratio 8 8 8 8 Water-oil ratio 0. 1 0. 1 0. 1 0. 1 Product distribution, weight%

Dry gas 0.98 1. 06 0. 45 1. 11 LPG 7.74 8. 46 5. 94 6. 86 Gasoline 84. 00 82. 25 86. 60 81. 71 Light diesel 4. 06 4. 51 3 43 5. 35 Heavy diesel 1.32 1. 56 1. 01 1. 98 Coke 1. 86 2. 15 2. 55 2. 98 Loss 0.04 0. 01 0. 02 0. 01 Gasoline properties

RON 88. 2 90. 1 88. 6 90. 2

M0N 80. 0 80. 2 80. 1 79. 1 Sulfur, pm 44 150. 6 50. 678 Nitrogen, m 0. 5 1. 5 1. 50 5. 0 Aromatics,% 26. 2 21. 8 8. 20 56. 8 Alkenes,% by weight 13. 4 17. 8 25. 9 4. 8

53. 4 53. 1 59. 4 29.2 Normal n-fluorene 5. 0 4. 9 5. 1 4. 9 Iso-hydrocarbon 48. 4 48. 2 54. 3 24. 3

7. 0 7. 3 6. 5 9. 2 Table 15

Catalyst A carbon deposit,% by weight 1. 1 1. 1 1. 1 Operating conditions

Reaction temperature, ° c 450 400 520 weight hourly space velocity, hour 1 ¹ 4 4 15 agent oil ratio 8 12 6 water oil ratio 0.1 1 0. 10 0. 15 product distribution, weight ° /.

Dry gas 0.98 0. 92 1. 98 LPG 7.74 6. 15 9. 08 Gasoline 84. 00 85. 10 81. 97 Light diesel 4. 06 4. 27 3. 64 Heavy diesel 1. 32 1. 46 1. 12 Coke 1. 86 2. 08 2. 16 Loss 0.04 0. 02 0. 05 Gasoline properties Raw material properties

RON 91. 3 88. 2 88. 0 90. 1

M0N 79. 5 80. 0 80. 0 80. 0 Sulfur, ppm 200 44 56 40 Nitrogen, Ppm 30 0. 5 0. 5 0. 6 Aromatics,% 24. 3 26. 2 25. 8 31. 4 Olefins , Weight% 37. 8 13. 4 12. 3 15. 6 alkanes, weight% 29. 6 53. 4 54. 7 46. 1 normal paraffin 5. 3 5. 0 4. 9 5. 0 isoparaffin 25 . 3 48. 4 49. 8 41. 1

8. 3 7. 0 7. 2 6. 9 Table 16

Catalyst A carbon deposit, weight% 0.90 1. 1 1. 3 Operating conditions

Reaction temperature, ° c 450 450 450 weight hourly space velocity, hour ^ 4 4 4 agent oil ratio 8 8 8 water oil ratio 0. 1 0. 1 0. 1 product distribution, weight ° /.

Dry gas 1. 23 0. 98 0. 56 Liquefied gas 9. 56 7. 74 3. 53 Gasoline 81. 89 84. 00 89. 20 Light diesel 3. 87 4. 06 3. 76 Heavy diesel 1. 35 1. 32 1. 23 Coke 2. 05 1. 86 1. 67 Loss 0.05 0. 04 0. 05 Gasoline properties Raw material properties

RON 91. 3 88. 1 88. 2 89. 2

M0N 79. 5 80. 1 80. 0 80. 0 Sulfur, ppm 200 40 44 56 Nitrogen, ppm 30 0. 3 0. 5 0. 5 Aromatics, weight% 24. 3 27. 1 26. 2 25. 8 Olefins , Weight ° /. 37. 8 11. 3 13. 4 20. 3 alkanes, weight% 29. 6 54. 5 53. 4 46. 4 n-alkanes 5. 3 5. 1 5. 0 5. 2 isomeric alkanes 25. 3 49. 4 48. 4 41.2 Cyclopentene, weight% 8. 2 7. 1 7. 0 7. 5 Table 17

Gasoline injection port g h Catalyst A carbon deposit, weight% 0.93 0. 92 of which hydrogen in carbon, weight% 10. 14 8. 34 Operating conditions

Reaction temperature, ° c 480 480 weight hourly space velocity, hour — ¹ 4 7 agent oil ratio 8 8 water oil ratio 0. 1 0. 1 product distribution, weight%

Dry gas 1. 32 1. 04 LPG 10. 16 8. 47 Gasoline 81. 55 84. 07 Light diesel 3. 58 3. 37 Heavy diesel 1. 31 1. 13 Coke 2. 03 1. 88 Loss 0.05 0. 04 Gasoline properties

RON 91. 3 88. 5 88. 9

M0N 79. 5 80. 0 80. 0 Sulfur, ppm 200 45 46 Nitrogen, Ppm 30 0. 5 0.5 Aromatics, weight% 24. 3 27. 1 26. 8 Olefins, weight% 37. 8 11. 6 14 4 fluorene, weight% 29. 6 54. 2 51. 5 n-paraffin 5.3 5. 1 5. 2 isomer fluorene 25. 3 49. 1 46. 3

8. 2 7. 1 7. 3

Claims

Rights request

1. A catalytic conversion method for reducing the content of olefins, sulfur, and nitrogen in gasoline by contacting a preheated gasoline fraction with a catalyst having a carbon deposition amount of ≤2.0% by weight and a temperature lower than 600 ° C, at 100 The reaction occurs under the conditions of ~ 600 ° C, 130 ~ 450Kpa, weight hourly space velocity l UOh- ¹ catalyst and gasoline distillate weight ratio of 2-20, water vapor and gasoline distillate weight ratio of 0 ~ 0.3. The reaction product and the regenerant; the regenerant is recycled after being stripped and regenerated.

2. The method of claim 1, wherein the gasoline fraction is selected from the group consisting of a primary processed gasoline fraction, a secondary processed gasoline fraction, or a mixture of one or more of the foregoing gasoline fractions.

3. The method of claim 2, wherein the gasoline fraction can be a full fraction or a narrow fraction.

4. The method of claim 1, wherein the active component of the catalyst for reaction with gasoline fractions is selected from the group consisting of Y-type or HY-type zeolites with or without rare earth and / or phosphorus, and with or without rare earth and / or phosphorus. One or more of super-stable Y-type zeolite, ZSM-5 series zeolite or high-silica zeolite with a five-membered ring structure, beta zeolite, and ferrierite.

5. The method of claim 1, wherein said catalyst that reacts with gasoline fractions and has a temperature lower than 600 ° C is selected from one of the following three types of catalysts: ① the amount of coke deposited is ≤0.10% by weight regeneration catalyst ; ② catalyst with a carbon deposition amount of 0.10 to 0.90% by weight; ③ catalyst with a carbon deposition amount of 0.90 to 2.0% by weight.

6. The method of claim 5, wherein the amount of coke deposited in the reaction is ≦ 0.10 weight /. At least a part of the regeneration catalyst should be cooled before reacting with the gasoline fraction; this reaction process can be implemented separately on the gasoline catalytic conversion unit, or it can be implemented in combination with a catalytic cracking unit that processes conventional catalytic cracking raw materials.

7. The method of claim 6, wherein when combined with a catalytic cracking unit for processing conventional FCC raw materials, the gasoline fraction and the conventional FCC raw materials are reacted in respective reactors respectively; a settler, a stripper and subsequent separation The systems can be shared or independent of each other; the catalyst regeneration system is shared.

8. The method of claim 6, wherein the reaction process is performed under the following conditions: the reaction temperature is 100 to 600 ° C, the reaction pressure is 130 to 450 kpa, and the weight hourly space velocity is 1 to 120 hours-the weight of the catalyst and gasoline fractions 1。 The ratio is 2 to 15, the weight ratio of water vapor to gasoline fraction is 0 to 0.1.

9. The method of claim 8, wherein the reaction process is performed under the following conditions: the reaction temperature is 150 to 550 ° C, the reaction pressure is 250 to 400 kpa, and the weight hourly space velocity is 2 to 100 hours-the weight of the catalyst and gasoline fractions 01〜0. 05。 The ratio is 3 to 10, the weight ratio of water vapor to gasoline fraction is 0.01 to 0.05.

10. The method of claim 5, wherein at least a part of the catalyst having a coke deposit amount of 0.1 to 0.90% by weight should be cooled first, and then reacted with the gasoline fraction; the reaction process can be performed at It can be implemented separately on the gasoline catalytic conversion device, and it can also be used with conventional catalytic cracking raw materials. The cracking unit is jointly implemented.

11. The method of claim 10, wherein when combined with a catalytic cracking unit for processing conventional catalytic cracking raw materials, the gasoline fraction and the conventional catalytic cracking raw materials are reacted in respective reactors respectively; a settler, a stripper and subsequent separation The systems can be shared or independent of each other; the catalyst regeneration system is shared.

12. The method of claim 10, wherein the reaction process is performed under the following conditions: a reaction temperature of 300-600. (:, Reaction pressure 130 ~ 450Kpa, weight hourly space velocity 1 ~ 120h- weight ratio of catalyst to gasoline fraction 2-15, weight ratio of water vapor to gasoline fraction 0 ~ 0.1.

13. The method of claim 12, wherein the reaction process is performed under the following conditions: reaction temperature 350 ~ 550. C. Reaction pressure 250 ~ 400Kpa, weight hourly space velocity 2 ~ 100h- weight ratio of catalyst to gasoline fraction is 3 ~ 10, weight ratio of water vapor to gasoline fraction is 0.01 to 0.05.

14. The method of claim 5, wherein the catalyst reacting with the gasoline fraction is a catalyst to be produced with a carbon deposition amount of 0.90 to 2.0 wt%, the reaction process is performed in a stripping section, and The stripping section can be selected from one of the following three types: ① a conventional settler stripping section; ② a stripping section which is integrated with a dense phase bed of a catalyst in a fluidized bed reactor; ③ in catalytic cracking A container capable of performing catalyst stripping in the device.

15. The method of claim 14, wherein the gasoline fraction is injected into the stripping section at a position of 10 to 60% of the height of the dense phase bed of the catalyst in the stripping section.

16. The method of claim 15, wherein the gasoline fraction is injected into the stripping section from 15 to 55% of the height of the dense phase bed of the catalyst in the stripping section.

17. The method of claim 14, wherein the reaction process is performed under the following conditions: a reaction temperature of 400-550. (:, Reaction pressure 130 ~ 450Kpa, weight hourly space velocity 1 ~ 50h- weight ratio of catalyst to gasoline fraction 3 ~ 20, weight ratio of water vapor to gasoline fraction 0.03 to 0.30

18. The method of claim 17, wherein the reaction process is performed under the following conditions: a reaction temperature of 420 to 520 ° C, a reaction pressure of 250 to 400Kpa, and a weight hourly space velocity of 2 to 40h. 05-0. 30。 For 4-18, the weight ratio of water vapor to gasoline fraction is 0. 05-0. 30.

19. The method of claim 7 or 11, wherein the catalyst contacted with the gasoline fraction and the catalyst contacted with the conventional catalytic cracking feedstock may be the same or different.