CN107365600B

CN107365600B - Method for producing catalytic reforming raw material by hydrofining non-petrochemical naphtha and reaction device thereof

Info

Publication number: CN107365600B
Application number: CN201610318178.XA
Authority: CN
Inventors: 陈强; 朱豫飞; 索娅; 张琪; 赵俊鹏; 王传付
Original assignee: Shenhua Group Corp Ltd; National Institute of Clean and Low Carbon Energy
Current assignee: China Energy Investment Corp Ltd; National Institute of Clean and Low Carbon Energy
Priority date: 2016-05-13
Filing date: 2016-05-13
Publication date: 2020-04-21
Anticipated expiration: 2036-05-13
Also published as: CN107365600A

Abstract

The invention relates to the field of non-petrochemical oil product processing, and discloses a method for producing a catalytic reforming raw material by hydrofining non-petrochemical naphtha and a reaction device thereof. The method comprises the steps of carrying out first-stage hydrofining reaction on non-petrochemical naphtha, carrying out first-stage impurity removal on a first-stage hydrofining reaction product, and carrying out second-stage hydrofining reaction on a residual reaction product material subjected to first-stage impurity removal. The device comprises a first-stage hydrofining reactor, a first-stage impurity removal unit and a second-stage hydrofining reactor, wherein the first-stage hydrofining reactor and the second-stage hydrofining reactor respectively comprise a catalyst bed layer, a material inlet and a material outlet; the material outlet of the first-stage hydrofining reactor is connected with the material inlet of the second-stage hydrofining reactor through the first-stage impurity removing unit. The invention solves the problem of high added value utilization of non-petrochemical naphtha and can carry out hydrofining reaction under the relatively mild condition.

Description

Method for producing catalytic reforming raw material by hydrofining non-petrochemical naphtha and reaction device thereof

Technical Field

The invention relates to the field of non-petrochemical oil product processing, in particular to a method for producing a catalytic reforming raw material by hydrofining non-petrochemical naphtha and a reaction device thereof.

Background

Catalytic reforming is a process for producing high-octane gasoline and light aromatic hydrocarbons (benzene, toluene and xylene, abbreviated as BTX) from naphtha. According to the reaction process, the characteristics of the catalyst and the composition of the product, the reforming raw material is required to have the characteristics of high potential content of aromatic hydrocarbon and low sulfur and nitrogen content (generally, the sulfur and nitrogen content is required to be less than 0.5 mu g/g). The raw material sources of the existing catalytic reforming device in China are mainly straight run naphtha and hydrocracking naphtha in the petroleum refining process. They are all pre-hydrogenated to remove olefins and impurities such as sulfur and nitrogen before they can be used as feedstock for the reforming unit.

With the rapid development of the coal chemical industry in recent years, non-petrochemical naphtha, especially coal-based naphtha, will also become an important source of reforming raw materials. Since 2014 the next half year, the international crude oil price is the first to explore, the economical efficiency of the coal chemical industry is subject to more and more severe tests, and the improvement of the deep processing capacity of the coal-based oil product is urgent. The coal-based naphtha is used as the raw material for producing BTX by catalytic reforming, so that the method has good applicability and can effectively improve the economy of coal chemical engineering projects. The coal-based oil product mainly refers to coal direct liquefaction oil, coal indirect liquefaction oil and/or coal pyrolysis oil. The composition difference of coal-based naphtha and petroleum-based naphtha is large, taking straight-run naphtha and naphtha fraction of direct coal liquefaction oil as an example, generally, the sulfur content of the straight-run naphtha is less than 100 mu g/g, the nitrogen content is less than 5 mu g/g, and the potential content of aromatic hydrocarbon is less than 50 wt%; and the sulfur content in the corresponding fraction in the coal direct liquefaction oil exceeds 300 mu g/g, the nitrogen content exceeds 500 mu g/g, and the potential content of aromatic hydrocarbon is more than 60 percent by weight. Therefore, the non-petrochemical naphtha is a high-quality raw material for catalytic reforming, and at the same time, no catalytic reforming industrialized process or device which simply uses the non-petrochemical naphtha as the raw material exists at present, but the existing catalytic reforming pre-hydrogenation device can not meet the requirement that the sulfur and nitrogen content is less than 0.5 mu g/g when the non-petrochemical naphtha with higher sulfur and nitrogen content, such as coal-based naphtha, is processed.

Disclosure of Invention

The invention aims to provide a catalytic reforming industrial process or device which does not use non-petrochemical naphtha as a raw material in the prior art, and provides a method for producing a catalytic reforming raw material by hydrofining the non-petrochemical naphtha and a reaction device thereof.

In order to achieve the above object, in a first aspect, the present invention provides a method for producing a catalytic reforming raw material by hydrorefining a non-petrochemical naphtha, the method comprising: performing a first-stage hydrofining reaction on the coal-based non-petrochemical naphtha, performing first-stage impurity removal on a product of the first-stage hydrofining reaction, and performing a second-stage hydrofining reaction on a residual reaction product material subjected to the first-stage impurity removal; wherein the first-stage hydrofining reaction conditions comprise: the temperature is 280-380 ℃, the hydrogen partial pressure is 2-8MPaG, the volume space velocity is 1-8h^-1The volume ratio of hydrogen to oil is 100-600; the second-stage refining reaction conditions include: the temperature is 300-390 ℃, the hydrogen partial pressure is 2-8MPaG, the volume space velocity is 1-8h^-1The volume ratio of hydrogen to oil is 100-600; the first-stage impurity removal enables the sulfur content in the residual reaction product material after the first-stage impurity removal to be reduced to below 30 mu g/g and the nitrogen content to be reduced to below 5 mu g/g.

In a second aspect, the invention provides a reaction device for producing a catalytic reforming raw material by hydrofining non-petrochemical naphtha, which comprises a first-stage hydrofining reactor, a first-stage impurity removal unit and a second-stage hydrofining reactor, wherein the first-stage hydrofining reactor and the second-stage hydrofining reactor respectively comprise a catalyst bed layer, a material inlet and a material outlet; the material outlet of the first-stage hydrofining reactor is connected with the material inlet of the second-stage hydrofining reactor through a first-stage impurity removing unit; the first stage impurity removal unit is used for reducing the sulfur content and the nitrogen content in the material from the material outlet of the first stage hydrofining reactor.

Through the technical scheme, the problem of high added value utilization of non-petrochemical naphtha, particularly coal-based naphtha, is solved, the non-petrochemical naphtha hydrofining product supplements the types of catalytic reforming raw materials, and the economical efficiency of coal chemical engineering projects is improved. In addition, the invention can carry out hydrofining reaction under mild conditions, thus reducing the operation difficulty and equipment investment.

In a preferred embodiment of the present invention, the product of the first stage of hydrorefining reaction is preheated and then exchanges heat with a newly introduced material containing non-petrochemical naphtha, and the inventors of the present invention found that when a heating furnace is used to heat a fresh non-petrochemical naphtha raw material, a furnace tube is prone to coking because the raw material is heated unevenly and locally at a high temperature, and the raw material contains more unsaturated hydrocarbons, such as aromatic hydrocarbons, olefins, and dienes, which are prone to polymerization reaction under heating to generate macromolecular compounds, thereby causing coking of the furnace tube. And the newly introduced non-petrochemical naphtha is subjected to mild temperature rise to reduce the formation of macromolecular compounds by further heating the first-stage hydrofining reaction product and then exchanging heat with the newly introduced material containing the non-petrochemical naphtha, so that coking in a heating furnace pipe is reduced, and the service cycle of the heating furnace pipe is prolonged.

In another preferred embodiment of the invention, the first-stage hydrofining reaction and/or the second-stage hydrofining reaction are/is carried out in an up-flow fixed bed reactor, so that the gas-phase reaction raw materials are dispersed more uniformly, the bed pressure drop is reduced, the coking is more and more serious along with the extension of the reaction time, and the effect of reducing the pressure drop is more obvious.

Additional features and advantages of the invention will be set forth in the detailed description which follows.

Drawings

The accompanying drawings, which are included to provide a further understanding of the invention and are incorporated in and constitute a part of this specification, illustrate embodiments of the invention and together with the description serve to explain the principles of the invention and not to limit the invention. In the drawings:

FIG. 1 is a schematic view of the structure of a hydrorefining reaction apparatus according to a preferred embodiment of the present invention;

FIG. 2 is a schematic view of the structure of a hydrorefining reaction apparatus according to another preferred embodiment of the present invention;

FIG. 3 is a schematic view showing the structure of a hydrorefining reaction apparatus according to still another preferred embodiment of the present invention.

Detailed Description

The following describes in detail specific embodiments of the present invention. It should be understood that the detailed description and specific examples, while indicating the present invention, are given by way of illustration and explanation only, not limitation.

The endpoints of the ranges and any values disclosed herein are not limited to the precise range or value, and such ranges or values should be understood to encompass values close to those ranges or values. For ranges of values, between the endpoints of each of the ranges and the individual points, and between the individual points may be combined with each other to give one or more new ranges of values, and these ranges of values should be considered as specifically disclosed herein.

In the present invention, the unit "MPaG" used indicates gauge pressure, that is, pressure indicated by a pressure gauge, in the case where no description is made to the contrary.

The invention provides a method for producing a catalytic reforming raw material by hydrofining non-petrochemical naphtha, which comprises the following steps: carrying out a first-stage hydrofining reaction on non-petrochemical naphtha, carrying out first-stage impurity removal on a product of the first-stage hydrofining reaction, and carrying out a second-stage hydrofining reaction on a residual reaction product material subjected to the first-stage impurity removal;

wherein the first-stage hydrofining reaction conditions comprise: the temperature is 280-380 ℃, the hydrogen partial pressure is 2-8MPaG, the volume space velocity is 1-8h^-1The volume ratio of hydrogen to oil is 100-600; the second-stage hydrofining reaction conditions comprise: the temperature is 300-390 ℃, the hydrogen partial pressure is 2-8MPaG, the volume space velocity is 1-8h^-1The volume ratio of hydrogen to oil is 100-600; the first-stage impurity removal reduces the sulfur content to below 30 mu g/g (such as 5-30 mu g/g) and the nitrogen content to below 5 mu g/g (0.8-5 mu g/g) of the residual reaction product material after the first-stage impurity removal.

Preferably, the first stage hydrofinishing reaction conditions include: the temperature is 320-340 ℃, the hydrogen partial pressure is 2.5-4.5MPaG, and the volume space velocity is 2-6h^-1The volume ratio of hydrogen to oil is 180-400.

Preferably, the second-stage hydrofinishing reaction conditions include: the temperature is 320 ℃ and 340 ℃, and the hydrogenPartial pressure of 2.7-4.5MPaG and volume space velocity of 2-6h^-1The volume ratio of hydrogen to oil is 180-400.

According to the present invention, the first stage of dehalogenation may be carried out in any manner known in the art so long as the sulfur and nitrogen contents of the reaction product stream remaining after the first stage of dehalogenation are reduced to within the above-mentioned ranges, for example, a gas-oil-water three-phase separation may be carried out to reduce the sulfur and nitrogen contents, followed by further nitrogen desulfurization operations (e.g., evaporative separation) to further reduce the sulfur and nitrogen contents (particularly, the hydrogen sulfide and ammonia contents). Preferably, the first-stage impurity removing mode is as follows: mixing the first-stage hydrofining reaction product with water, and then carrying out gas-oil-water three-phase separation, so that the first-stage oil phase obtained by gas-oil-water three-phase separation is subjected to evaporation separation, thereby further separating hydrogen sulfide and ammonia gas.

More preferably, the product of the first stage hydrofinishing reaction is mixed with water in a ratio of 100: 2-5 weight ratio.

More preferably, the gas-oil-water three-phase separation conditions include: the temperature is 15-60 deg.C, and the pressure is 0.1-0.4MPaG lower than the hydrogen partial pressure of the first stage of hydrofining reaction. In order to control the temperature of the gas-oil-water three-phase separation to meet the range and better perform the gas-oil-water three-phase separation, the product of the first-stage hydrofining reaction is mixed with water and then is cooled (can be performed by a cooler) and then is subjected to the gas-oil-water three-phase separation.

More preferably, the conditions of the evaporative separation include: the temperature is 150 ℃ and 230 ℃, and the pressure is 0.8-1.5 MPaG. The alkane content below C4 in the first oil phase can be effectively reduced, such as to be below 0.2 wt% through evaporation separation.

According to a preferred embodiment of the invention, the method further comprises: and (3) performing second-stage impurity removal and/or fractionation on a product of the second-stage hydrofining reaction, wherein the second-stage impurity removal enables the sulfur content of the residual material subjected to the second-stage impurity removal to be reduced to be lower than 0.5 mu g/g and the nitrogen content to be reduced to be lower than 0.5 mu g/g.

In this preferred embodiment, the second stage of dehalogenation may be carried out in any manner known in the art as long as the sulfur and nitrogen contents of the remaining reaction product stream after the second stage of dehalogenation are reduced to within the above ranges, for example, a gasoil-water three-phase separation may be carried out to reduce the sulfur and nitrogen contents, followed by further denitrogenation operations (e.g., evaporative separation) to further reduce the sulfur and nitrogen contents (particularly the hydrogen sulfide and ammonia contents). More preferably, the second-stage impurity removal mode is as follows: and mixing the product of the second-stage hydrofining reaction with water, and then carrying out gas-oil-water three-phase separation, so that a second-stage oil phase obtained by gas-oil-water three-phase separation is subjected to evaporation separation to further separate hydrogen sulfide and ammonia gas.

Further preferably, the second-stage hydrofinishing reaction product is mixed with water in a ratio of 100: 2-5 weight ratio.

Further preferably, the gas-oil-water three-phase separation conditions include: the temperature is 15-60 deg.C, and the pressure is 0.1-0.4MPaG lower than the hydrogen partial pressure of the second-stage hydrofining reaction. In order to control the temperature of the gas-oil-water three-phase separation to meet the range and better perform the gas-oil-water three-phase separation, the second-stage hydrofining reaction product is mixed with water and then is cooled (which can be performed by a cooler) and then is subjected to the gas-oil-water three-phase separation.

Further preferably, the evaporative separation conditions include: the temperature is 180 ℃ and 260 ℃, and the pressure is 0.8-1.8 MPaG. The content of alkanes with less than C4 in the second-stage oil phase can also be effectively reduced, such as to less than 0.2 wt% by evaporation separation.

In the preferred embodiment, fractional distillation may be carried out in a manner conventional in the art to separate a refined naphtha that may be used as a catalytic reforming feedstock. More preferably, the fractionation results in a product oil having a distillation range of 80-180 ℃.

In the present invention, the first-stage impurity removal and the second-stage impurity removal may be performed in the same manner or under different conditions. As can be understood by those skilled in the art, in order to reduce the influence of impurities in water on the hydrofining effect, the water used in the invention is preferably desalted water, and each index of the desalted water meets the GB/T12145-2008 medium-pressure boiler feed water quality standard.

According to the present invention, the hydrogen source used in the hydrorefining reaction can be supplied to the first-stage hydrorefining reaction and the second-stage hydrorefining reaction, respectively, and generally, in order to ensure sufficient reaction, the supply amount of hydrogen is larger than the actually required amount of hydrogen, so that a certain amount of hydrogen enters the next step along with the first-stage hydrorefining reaction product or the second-stage hydrorefining reaction product. Therefore, in order to improve the utilization rate of the raw materials, the method further comprises the step of providing at least part of hydrogen for the first-stage hydrofining reaction by taking the gas phase collected by gas-oil-water three-phase separation as a hydrogen source, and preferably, the method further comprises the following steps: the gas phase collected by gas-oil-water three-phase separation is used as a hydrogen source to provide hydrogen for the first-stage hydrofining reaction, and the sulfur content of the hydrogen source for providing the hydrogen for the second-stage hydrofining reaction is controlled to be less than (500ppm)0.05 volume percent, and the ammonia content is controlled to be less than (100ppm)0.01 volume percent. Wherein, controlling the sulfur content of the hydrogen source in the second-stage hydrofining reaction within the range is more beneficial to ensuring the sulfur content and the nitrogen content in the final product.

In another embodiment of the present invention, the method further comprises desulfurizing the gas phase collected by gas-oil-water three-phase separation, and using the desulfurized gas phase as a hydrogen source to provide at least part of hydrogen for the two-stage hydrofining reaction.

Generally, in order to promote the first-stage hydrofining reaction, the non-petrochemical, such as coal-based naphtha, is preheated and then subjected to the hydrofining reaction, i.e., the non-petrochemical, such as coal-based naphtha and the hydrogen source, are generally heated to a certain temperature by a heating furnace and then contacted with a catalyst to carry out the hydrofining reaction, and the non-petrochemical, such as coal-based naphtha and the hydrogen source, can be preheated by heating (with the aid of a heating furnace) and heat exchange with the first-stage hydrofining reaction product. In order to effectively reduce coking in the heating furnace under the condition of ensuring smooth proceeding of the first-stage hydrofining reaction, preferably, the first-stage hydrofining reaction product is preheated and then exchanges heat with a newly introduced material containing non-petrochemical substances, such as coal-based naphtha. It will be understood by those skilled in the art that the non-petrochemical species, e.g., coal-based naphtha, and the hydrogen source can be provided independently of each other or as a mixture (i.e., the aforementioned non-petrochemical species, e.g., coal-based naphtha-containing material is a non-petrochemical species, e.g., a mixture of coal-based naphtha and the hydrogen source), but is preferably provided as a mixture for convenience of industrial operation, and when provided as a mixture, the heat exchange is performed on the basis of the mixture.

Similarly, as will be understood by those skilled in the art, in order to promote the second-stage hydrofining reaction, the material entering the second-stage hydrofining reaction (i.e., the material is preheated to a certain temperature and then enters the second-stage hydrofining reaction) is preheated (i.e., the material is preheated to a certain temperature and then enters the second-stage hydrofining reaction), and the material can be preheated by heating (with a heating furnace) and exchanging heat with the second-stage hydrofining reaction product, i.e., the first-stage impurity-removed reaction product can exchange heat with the second-stage hydrofining reaction product and then be heated (with a heating furnace) as required and then be sent to the second-stage hydrofining reaction.

According to the present invention, in order to further improve the efficiency of the hydrorefining reaction, the first-stage hydrorefining reaction and/or the second-stage hydrorefining reaction is carried out in an upflow fixed bed reactor.

According to the present invention, the non-petrochemical, e.g., coal-based naphtha, is a variety of non-petrochemical naphthas common in the art, e.g., coal-based naphtha and/or biomass naphtha. Preferably, the non-petrochemical, e.g. coal-based naphtha is a naphtha fraction with a distillation range of 60-150 ℃, the sulfur content is more than 600 μ g/g (less than 1500 μ g/g, such as 1000-.

In a particularly preferred embodiment of the present invention, the present invention provides a process for producing a catalytic reforming feedstock by hydrofinishing a non-petrochemical naphtha, comprising the steps of:

(1) continuous introduction of non-petrochemical, e.g., coal-based naphtha, into a first stage hydrofinishing reactorThe first-stage hydrofining reaction is carried out, and the first-stage hydrofining reaction conditions comprise: the temperature is 280-380 ℃, the hydrogen partial pressure is 2-8MPaG, the volume space velocity is 1-8h^-1The hydrogen-oil volume ratio is 100-600 (preferably, the first-stage hydrofining reaction conditions comprise the temperature of 320-340 ℃, the hydrogen partial pressure of 2.5-4.5MPaG and the volume space velocity of 2-6h^-1The volume ratio of hydrogen to oil is 180-400);

(2) preheating a product of the first-stage hydrofining reaction, and then exchanging heat with a material which is newly introduced in the step (1) and contains non-petrochemical substances, such as coal-based naphtha;

(3) carrying out first-stage impurity removal on the first-stage hydrofining reaction product after heat exchange to reduce the sulfur content of the residual reaction product material subjected to the first-stage impurity removal to below 30 mu g/g and the nitrogen content of the residual reaction product material subjected to the first-stage impurity removal to below 5 mu g/g, wherein the first-stage impurity removal mode is as follows: mixing the first-stage hydrofining reaction product with water, and then carrying out gas-oil-water three-phase separation, so that a first-stage oil phase obtained by gas-oil-water three-phase separation is subjected to evaporation separation to further separate hydrogen sulfide and ammonia gas;

(4) introducing the residual reaction product material after the first-stage impurity removal into a second-stage hydrofining reactor to carry out second-stage hydrofining reaction, wherein the second-stage hydrofining reaction conditions comprise: the temperature is 300-390 ℃, the hydrogen partial pressure is 2-8MPaG, the volume space velocity is 1-8h^-1The volume ratio of hydrogen to oil is 100-600 (preferably, the second-stage hydrofining reaction conditions comprise the temperature of 320-340 ℃, the hydrogen partial pressure of 2.7-4.5MPaG and the volume space velocity of 2-6h^-1The volume ratio of hydrogen to oil is 180-400);

(5) and (2) carrying out second-stage impurity removal on the second-stage hydrofining reaction product to reduce the sulfur content of the residual reaction product material subjected to second-stage impurity removal to be below 0.5 mu g/g and the nitrogen content of the residual reaction product material subjected to second-stage impurity removal to be below 0.5 mu g/g, wherein the second-stage impurity removal mode is as follows: mixing the second-stage hydrofining reaction product with water, and then carrying out gas-oil-water three-phase separation, so that a second-stage oil phase obtained by gas-oil-water three-phase separation is subjected to evaporation separation to further separate hydrogen sulfide and ammonia gas;

(6) fractionating the reaction product after the second-stage impurity removal to obtain a catalytic reforming raw material;

wherein the non-petrochemical naphtha, such as coal-based naphtha, has a distillation range of 60-150 ℃, a sulfur content of 600 [ mu ] g/g or more and a nitrogen content of 500 [ mu ] g/g or more; the first-stage hydrofining reactor and/or the second-stage hydrofining reactor is an up-flow fixed bed reactor.

In the above-mentioned particularly preferred embodiments, the preferred operation modes and conditions of each step can adopt the above-mentioned modes and conditions, and are not described in detail herein.

According to the present invention, for the sake of clarity, the hydrofinishing catalyst used in the first-stage hydrofinishing reaction is referred to as "first hydrofinishing catalyst", and the hydrofinishing catalyst used in the second-stage hydrofinishing reaction is referred to as "second hydrofinishing catalyst".

Each of the first and second hydrofinishing catalysts may be any of various catalysts commonly used for hydrofinishing of non-petrochemical species, such as coal-based naphtha. Specifically, each of the first and second hydrofinishing catalysts may include a carrier, and a group VIB metal and a group VIII metal supported on the carrier, the group VIB metal is preferably molybdenum and/or tungsten, the group VIII metal is preferably cobalt and/or nickel, and the carrier may be various common porous heat-resistant inorganic oxides, preferably silica and/or alumina. The content of the group VIB metal and the group VIII metal on the carrier depends on the specific kind of the catalyst, and is not particularly limited. The first hydrofinishing catalyst and the second hydrofinishing catalyst may be the same or different. For example, the first and second hydrofinishing catalysts may be FD catalysts (Mo-Ni/Al) available from the chinese petrochemical compliant petrochemical research institute₂O₃Type catalyst).

To more conveniently control the temperature of the first stage hydrofinishing reaction and/or the second stage hydrofinishing reaction, the process may further comprise contacting cold hydrogen (such as a source of hydrogen at a temperature of from 10 to 80 ℃) with the first hydrofinishing catalyst (and/or the second hydrofinishing catalyst). As mentioned before, the cold hydrogen may also be provided from the gas phase (optionally desulphurised) collected from the gas-oil-water three-phase separation.

In addition, the reaction device for producing the catalytic reforming raw material by hydrofining the non-petrochemical naphtha comprises a first-stage hydrofining reactor, a first-stage impurity removing unit and a second-stage hydrofining reactor, wherein the first-stage hydrofining reactor and the second-stage hydrofining reactor respectively (independently) comprise a catalyst bed layer, a material inlet and a material outlet; the material outlet of the first-stage hydrofining reactor is connected with the material inlet of the second-stage hydrofining reactor through a first-stage impurity removing unit; the first stage impurity removal unit is used for reducing the sulfur content and the nitrogen content in the material (product of the first stage hydrofining reaction) from the material outlet of the first stage hydrofining reactor. Wherein the first-stage hydrofining reactor is used for enabling a hydrocarbon raw material (non-petrochemical, such as coal-based naphtha) and hydrogen to contact and react with a catalyst in a catalyst bed layer to obtain a first-stage hydrofining reaction product; the second-stage hydrofining reactor is used for enabling the material flow and the hydrogen from the first-stage impurity removal unit to be in contact with the catalyst in the catalyst bed layer to obtain a second-stage hydrofining reaction product.

In the invention, the first-stage impurity removal unit comprises a gas-oil-water three-phase separator and a stabilizing tower which are sequentially connected with a material outlet of the first-stage hydrofining reactor, an oil phase outlet of the gas-oil-water three-phase separator is connected with a material inlet of the stabilizing tower, and a material outlet of the stabilizing tower is connected with a material inlet of the second-stage hydrofining reactor. The gas-oil-water three-phase separator is mainly used for reducing the sulfur content and the nitrogen content of a first-stage hydrofining reaction product; the stabilizer is mainly used for evaporation separation to further reduce the sulfur content and the nitrogen content (particularly the hydrogen sulfide content and the ammonia content, and the alkane content below C4 can be effectively reduced) in the first-stage oil phase obtained by separation of a gas-oil-water three-phase separator. To better effect gas oil water three-phase separation, the first stage impurity removal unit may further comprise a cooler for reducing the temperature of the first stage hydrofinishing reaction product to a temperature suitable for gas oil water three-phase separation.

In a preferred embodiment of the present invention, the apparatus further comprises a second stage dehazing unit connected to the feed outlet of the second stage hydrofinishing reactor for reducing the sulphur content and the nitrogen content of the feed from the feed outlet of the second stage hydrofinishing reactor and/or a fractionation column.

More preferably, the second-stage impurity removal unit comprises a gas-oil-water three-phase separator and a stabilizing tower which are sequentially connected with a material outlet of the second-stage hydrofining reactor, an oil phase outlet of the gas-oil-water three-phase separator is connected with a material inlet of the stabilizing tower, and/or a material outlet of the stabilizing tower is connected with a material inlet of the fractionating tower. Similarly, the gas-oil-water three-phase separator is mainly used for reducing the sulfur content and the nitrogen content of the second-stage hydrofining reaction product; the stabilizer is mainly used for evaporation separation to further reduce the sulfur content and the nitrogen content (particularly the hydrogen sulfide content and the ammonia content, and the alkane content below C4 can be effectively reduced) in the second-stage oil phase obtained by separation of the gas-oil-water three-phase separator. To better effect gas oil water three phase separation, the second stage dehairing unit may further comprise a cooler for reducing the temperature of the second stage hydrofinishing reaction product to a temperature suitable for gas oil water three phase separation. The fractionating tower is used for fractionating materials sent out from the bottom (material outlet) of the stabilizing tower so as to obtain qualified catalytic reforming raw materials.

In the present invention, the apparatus may further include a hydrogen supply unit for supplying hydrogen to the first-stage hydrofinishing reactor and/or the second-stage hydrofinishing reactor.

In the invention, a gas phase outlet of the gas-oil-water three-phase separator is connected with a material inlet of the first-stage hydrofining reactor, so that a gas phase collected by the gas-oil-water three-phase separator is used as a hydrogen source to provide hydrogen for the first-stage hydrofining reactor. The hydrogen in the first-stage hydrofining reactor can be completely provided by the gas phase collected by the gas-oil-water three-phase separator, so that the gas-oil-water three-phase separator is only connected with the material inlet of the first-stage hydrofining reactor and is not directly connected with the second-stage hydrofining reactor. In order to further improve the efficiency of the hydrofining reaction, the gas-phase outlet of the gas-oil-water three-phase separator is connected with the material inlet of the first-stage hydrofining reactor through a desulfurizing tower so as to control the sulfur content in the gas phase released by the gas-phase outlet of the gas-oil-water three-phase separator.

In addition, in order to ensure that the hydrogen partial pressure in the first stage hydrofinishing reactor meets the requirements of the hydrofinishing reaction, the apparatus further comprises a gas compressor for compressing the gas (such as hydrogen gas) entering the first stage hydrofinishing reactor.

In another embodiment of the present invention, the gas phase outlet of the gas-oil-water three-phase separator may be connected to the material inlet of the second-stage hydrofining reactor through a desulfurizing tower, and is configured to enable the gas phase collected by the gas-oil-water three-phase separator to be desulfurized and then serve as a hydrogen source to provide hydrogen to the second-stage hydrofining reactor.

In the present invention, the hydrogen supply unit may be further connected to the catalyst bed to supply cold hydrogen to the catalyst bed to facilitate the adjustment of the temperature of the catalyst bed. As mentioned above, the cold hydrogen may also be provided from the gas phase collected by the gas-oil-water three-phase separator (optionally passed to a desulfurization tower for desulfurization), and thus, the gas phase outlet of the gas-oil-water three-phase separator may also be connected to the catalyst bed.

In the invention, the first-stage hydrofining reactor is connected with a heating unit for heating the material fed into the first-stage hydrofining reactor to a proper temperature. The heating unit comprises a heating furnace and a heat exchanger, one end of the heating furnace is connected with a material outlet of the first-stage hydrofining reactor, the other end of the heating furnace is connected with the heat exchanger, the heating furnace is used for preheating materials from the material outlet of the first-stage hydrofining reactor, the heat exchanger is used for exchanging heat between the materials preheated by the heating furnace and initial materials before entering the first-stage hydrofining reactor, and therefore the heated initial materials are sent into the first-stage hydrofining reactor. The heating furnace is arranged behind the first-stage hydrofining reactor, namely is connected with the material outlet of the first-stage hydrofining reactor, so that coking in the heating furnace can be effectively reduced under the condition of ensuring smooth hydrofining reaction.

Similarly, as will be understood by those skilled in the art, in order to promote the reaction in the second-stage hydrofining reactor, the material entering the second-stage hydrofining reactor is preheated (i.e., the material is preheated to a certain temperature and then enters the second-stage hydrofining reactor), and the material can be preheated by heating (with the help of a heating furnace) and heat exchanging with the second-stage hydrofining reaction product, i.e., the material can be heat-exchanged with the product sent out from the material outlet of the second-stage hydrofining reactor, and then heated (with the help of a heating furnace) as required and then sent into the second-stage hydrofining reactor. Therefore, the second-stage hydrofining reactor can also be connected with a heating unit, the heating unit comprises a heating furnace and a heat exchanger, the heat exchanger is used for exchanging heat between the material from the first-stage impurity removal unit and the product of the second-stage hydrofining reaction, one end of the heating furnace is connected with the heat exchanger, the other end of the heating furnace is connected with the material inlet of the second-stage hydrofining reactor, and the heating furnace is used for preheating the material after heat exchange, so that the heated material (from the first-stage impurity removal unit) is sent into the second-stage hydrofining reactor.

In order to further increase the efficiency of the hydrofinishing reaction, according to a preferred embodiment of the present invention, in the first stage hydrofinishing reactor and/or the second stage hydrofinishing reactor, the feed inlet is located at the bottom of the hydrofinishing reactor and the feed outlet is located at the top of the hydrofinishing reactor. More preferably, the first-stage hydrofinishing reactor and/or the second-stage hydrofinishing reactor is an upflow fixed bed reactor.

Fig. 1 shows a preferred embodiment of the device according to the invention.

As shown in fig. 1: the device mainly comprises a first-stage hydrofining reactor 4, a first-stage impurity removal unit, a second-stage hydrofining reactor 12, a second-stage impurity removal unit and a fractionating tower 17 which are connected in sequence; the first-stage hydrofining reactor and the second-stage hydrofining reactor are descending fixed bed reactors; the first-stage hydrofining reactor is connected with a heating unit, the heating unit comprises a heating furnace 3 and a heat exchanger 2, the heat exchanger 2 is used for exchanging heat between a material from a material outlet of the first-stage hydrofining reactor and a starting material (non-petrochemical, such as coal-based naphtha), one end of the heating furnace 3 is connected with the heat exchanger 2, the other end of the heating furnace is connected with a material inlet of the first-stage hydrofining reactor 4, and the heating furnace 3 is used for preheating the material after heat exchange, so that the heated starting material is sent into the first-stage hydrofining reactor 4; the second-stage hydrofining reactor is also connected with a heating unit, the heating unit comprises a heating furnace 11 and a heat exchanger 10, the heat exchanger 10 is used for exchanging heat between the material from the first-stage impurity removal unit and the second-stage hydrofining reaction product, one end of the heating furnace 11 is connected with the heat exchanger 10, the other end of the heating furnace 11 is connected with a material inlet of the second-stage hydrofining reactor 12, the heating furnace 11 is used for preheating the material after heat exchange, and thus the heated material (from the first-stage impurity removal unit) is sent into the second-stage hydrofining reactor 12;

wherein the first-stage hydrofining reactor 4 and the second-stage hydrofining reactor 12 respectively comprise a catalyst bed layer, a material inlet and a material outlet; the material outlet of the first-stage hydrofining reactor 4 is connected with the material inlet of the second-stage hydrofining reactor 12 through a first-stage impurity removing unit; the material outlet of the second-stage hydrofining reactor 12 is connected with the material inlet of the fractionating tower 17 through the second-stage impurity removing unit;

the first-stage impurity removal unit comprises a cooler 5, a gas-oil-water three-phase separator 6 and a stabilizer 8 which are sequentially connected with a material outlet of a first-stage hydrofining reactor 4, an oil phase outlet of the gas-oil-water three-phase separator 6 is connected with a material inlet of the stabilizer 8, and a material outlet of the stabilizer 8 is connected with a material inlet of a second-stage hydrofining reactor 12; the second-stage impurity removal unit comprises a cooler 13, a gas-oil-water three-phase separator 14 and a stabilizer 16 which are sequentially connected with a material outlet of a second-stage hydrofining reactor 12, wherein an oil phase outlet of the gas-oil-water three-phase separator 14 is connected with a material inlet of the stabilizer 16, and a material outlet of the stabilizer 16 is connected with a material inlet of the fractionating tower 17; the gas-oil-water three-phase separator 6 and the gas-phase outlet of the gas-oil-water three-phase separator 14 are connected with the material inlet of the first-stage hydrofining reactor 4 sequentially through a desulfurizing tower 18 and a gas compressor 19.

The method of use of the device described in figure 1 is as follows:

non-petrochemical, such as coal-based naphtha, is mixed with recycle hydrogen from a line 119 along a line 101 after being pressurized by a feed pump 1, the mixture enters a heat exchanger 2 along a line 102 to exchange heat with a first-stage hydrofining reaction product from a line 104, is heated by a heating furnace 3, and is sent to a first-stage hydrofining reactor 4 along a line 103;

the first stage hydrofining reactor 4 is provided with a catalyst bed, and circulating hydrogen from a pipeline 118 is arranged in the middle of the catalyst bed to be used as cold hydrogen to adjust the temperature of the catalyst bed. The reaction stream is subjected to olefin saturation, hydrofining desulfurization and hydrofining denitrification reactions in the first stage hydrofining reactor 4. The first stage hydrofinishing reaction product along the pipeline 104 exchanges heat with the first stage raw material of the pipeline 102 through the first stage feed heat exchanger 2, then is mixed with desalted water from the pipeline 125, enters the cooler 5 along the pipeline 105 for cooling, and then enters the gas-oil-water three-phase separator 6 for gas-oil-water three-phase separation. Sending sulfur-containing sewage obtained by gas-oil-water three-phase separation to a device; the first stage oil phase of the gas-oil-water three-phase separation is sent to a stabilizer 8 along a pipeline 107; the gas-oil-water three-phase separated gas is mixed with the gas from the gas line 113 of the gas-oil-water three-phase separator 14 along the line 106, and then enters the recycle hydrogen desulfurization tower 18, and further enters the recycle hydrogen compressor 19 along the line 116, and is used as recycle hydrogen. The oil phase separated from the first stage gas oil water three-phase enters the stabilizing tower 8 after heat exchange between the heat exchanger 7 and the first stage product oil of the stabilizing tower of the pipeline 108 along the pipeline 107, and dissolved H is evaporated and separated in the stabilizing tower 8₂S and C4 below, introducing the rich gas at the top of stabilizer 8 into fuel gas system 20, delivering to the device, and hydrorefining at the first stage at the bottomThe de-contaminated product oil is sent along line 108 to feed pump 9;

the first-stage hydrofining and impurity-removing product oil is pressurized by a feed pump 9 and then mixed with circulating hydrogen from a pipeline 122 along a pipeline 108, the mixture flow enters a heat exchanger 10 to exchange heat with a second-stage hydrofining reaction product from a pipeline 111, and then enters a heating furnace 11 along a pipeline 109 to be heated to the feeding temperature and enters a second hydrofining reactor 12;

the second-stage hydrofining reactor 12 is provided with a catalyst bed, and circulating hydrogen from a pipeline 121 is arranged in the middle of the catalyst bed to be used as cold hydrogen to adjust the temperature of the catalyst bed. The reaction stream is subjected to primarily hydrofinishing desulfurization and denitrification reactions in the second stage hydrofinishing reactor 12. The product of the second-stage hydrofining reactor is subjected to heat exchange with a second-stage raw material (a mixed material of first-stage product oil and hydrogen) from a pipeline 108 through a heat exchanger 10 along a pipeline 111, then is mixed with desalted water from a pipeline 126, then enters a cooler 13 along a pipeline 112 for cooling, and then enters a gas-oil-water three-phase separator 14 for gas-oil-water three-phase separation. Sending sulfur-containing sewage obtained by gas-oil-water three-phase separation to a device; the second stage oil phase of the gas-oil-water three-phase separation is sent to the stabilizer 16 along the line 114; the gas-oil-water three-phase separated gas is mixed with the gas from the gas-oil-water three-phase separator 6 in the gas line 106 along the line 113, and then enters the desulfurizing tower 18, and then enters the recycle hydrogen compressor 19 along the line 116, and is used as recycle hydrogen. The second-stage hydrofined and impurity-removed oil phase from the gas-oil-water three-phase separator 14 exchanges heat with the second-stage hydrofined and impurity-removed oil phase from the stabilizing tower 16 along a pipeline 115 through a heat exchanger 15 along a pipeline 114, enters the stabilizing tower 16, and is evaporated and separated into dissolved H in the stabilizing tower 16₂The alkane below S and C4, the rich gas at the top of the stabilizer tower 16 enters a fuel gas system 20 and is sent out of the device, and the second-stage hydrofined and impurity-removed oil (second-stage product oil) from the bottom of the stabilizer tower 16 is sent to the fractionating tower 17 along a pipeline 115;

and the second-stage hydrofined and impurity-removed oil enters a fractionating tower, hydrocarbons with the carbon number below 5 are separated from the top of the fractionating tower and are sent out of the device as light naphtha, and refined naphtha (heavy naphtha) which is a product at the bottom of the fractionating tower is sent into a catalytic reforming device and is used for producing high-octane gasoline and light aromatic hydrocarbons (benzene, toluene and xylene, BTX for short).

Fresh hydrogen (make-up hydrogen) from outside the device or recycle hydrogen from the reforming unit is respectively connected with the recycle hydrogen pipeline 117 and the pipeline 120 of the first-stage hydrofining reactor and the second-stage hydrofining reactor through the pipeline 123 and the pipeline 124, and can respectively supply hydrogen for the two hydrofining reactors or independently supply hydrogen for the first-stage hydrofining reactor or the second-stage hydrofining reactor;

desalted water from outside the apparatus is connected via

lines

125 and 126 to

lines

104 and 111 for the product of the first stage hydrofinishing reaction and the product of the second stage hydrofinishing reaction, respectively.

The apparatus shown in fig. 2 is substantially the same as the apparatus shown in fig. 1, except that the first-stage hydrofining reactor is connected with a heating unit, the heating unit comprises a heating furnace 3 and a heat exchanger 2, one end of the heating furnace 3 is connected with a material outlet of the first-stage hydrofining reactor 4, the other end of the heating furnace is connected with the heat exchanger 2, the heating furnace 3 is used for preheating the material from the material outlet of the first-stage hydrofining reactor 4, and the heat exchanger 2 is used for exchanging heat between the material preheated by the heating furnace 3 and the initial material before entering the first-stage hydrofining reactor 4, so as to send the heated initial material into the first-stage hydrofining reactor 4. The method of use is also substantially the same as the apparatus shown in fig. 1 and will not be described herein.

The apparatus shown in fig. 3 is substantially the same as the apparatus shown in fig. 1, except that the first-stage hydrofinishing reactor and the second-stage hydrofinishing reactor are upflow fixed bed reactors. The method of use is also substantially the same as the apparatus shown in fig. 1 and will not be described herein.

The present invention will be described in detail below by way of examples.

In the following examples, the determination of carbon and hydrogen elements is referred to the "determination method of an element analyzer for carbon, hydrogen, nitrogen and sulfur contents in organic chemicals" SNT 3005-; the sulfur content is measured by referring to SH/T0689 & lt 2000 & gt method for measuring total sulfur content of light hydrocarbon, engine fuel and other oil products (ultraviolet fluorescence method); the determination of the nitrogen content refers to a method for determining trace nitrogen in liquid petroleum hydrocarbon (an oxidation combustion method and a chemiluminescence method) in SH/T0657 and 2007; the oxygen content is measured by a subtraction method; the olefin content is obtained by analyzing the gasoline family composition (PONA) by the petrochemical engineering scientific research institute of China petrochemical corporation; simulated distillation was analyzed using ASTM D86, IBP denoting the initial boiling point; FBP denotes dry point; the height-diameter ratio of the catalyst bed layer is 2.5, the used catalyst is an FD catalyst (with the product number of FDS-4A) produced by China petrochemical smoothing petrochemical research institute, and the physical properties are as follows:

examples 1 to 5 are intended to illustrate the production process of a catalytic reforming raw material by hydrorefining a non-petrochemical naphtha such as coal-based naphtha and the reaction apparatus therefor according to the present invention.

Example 1

(1) Continuously introducing coal-based naphtha into a first-stage hydrofining reactor to perform a first-stage hydrofining reaction;

(2) preheating a product of the first-stage hydrofining reaction, and then exchanging heat with the mixed material of the coal-based naphtha and the hydrogen source newly introduced in the step (1), so that the temperature of the mixed material of the coal-based naphtha and the hydrogen source newly introduced reaches 300 ℃;

(3) performing first-stage impurity removal on a product of the first-stage hydrofining reaction after heat exchange, wherein the first-stage impurity removal mode is as follows: mixing the product of the first-stage hydrofining reaction with water, and then carrying out gas-oil-water three-phase separation, so that a first-stage oil phase obtained by gas-oil-water three-phase separation is subjected to evaporation separation in a stabilizing tower to further separate hydrogen sulfide and ammonia gas;

(4) introducing the reaction product material (namely the first-stage product oil) subjected to impurity removal at the first stage into a second-stage hydrofining reactor to carry out second-stage hydrofining reaction;

(5) and (3) carrying out second-stage impurity removal on the second-stage hydrofining reaction product, wherein the second-stage impurity removal mode is as follows: mixing the second-stage hydrofining reaction product with water, and then carrying out gas-oil-water three-phase separation, so that a second-stage oil phase obtained by gas-oil-water three-phase separation is subjected to evaporation separation in a stabilizing tower to further separate hydrogen sulfide and ammonia gas;

(6) fractionating a reaction product material (namely second-stage product oil) subjected to second-stage impurity removal to obtain a catalytic reforming raw material;

as shown in fig. 2, the first-stage hydrofining reactor and the second-stage hydrofining reactor are down-flow fixed bed reactors, and the analysis results of the first-stage hydrofining reaction conditions, the conditions of gas-oil-water three-phase separation in the first-stage impurity removal and the second-stage impurity removal and the evaporation separation in the stabilizer, the second-stage hydrofining reaction conditions, the coal-based naphtha components, and the catalytic reforming raw material product oil are shown in tables 1 and 2.

TABLE 1

TABLE 2

Example 2

Hydrofinishing was carried out in accordance with the procedure of example 1 except that the specific conditions of part of the procedure and the results of analysis of the product oil, etc. are shown in tables 3 and 4.

TABLE 3

TABLE 4

Example 3

Hydrofinishing was carried out in accordance with the procedure of example 1 except that the specific conditions of part of the steps and the results of analysis of the product oil, etc. are shown in tables 5 and 6.

TABLE 5

TABLE 6

Example 4

Except that the hydrorefining was carried out in the same manner as in example 1, the results of the analyses on the coal-based naphtha and the product oil used, etc. are shown in Table 7.

TABLE 7

Example 5

Hydrofinishing was carried out in accordance with the procedure of example 1, except that, as shown in FIG. 3, the first-stage hydrofinishing reactor and the second-stage hydrofinishing reactor were upflow fixed bed reactors, and the analysis results of the product oil are shown in Table 8.

TABLE 8

Comparative example 1

Hydrofining was carried out in accordance with the procedure of example 1, except that the first-stage hydrofining reaction was carried out at a reaction temperature of 350 ℃, a hydrogen partial pressure of 10MPaG and a volume space velocity of 0.5h^-1The hydrogen-oil ratio (v/v) was 800, and the results of analysis of the product oil are shown in Table 9.

Comparative example 2

Hydrofinishing was carried out as in example 1, except that the second stage of the hydrofinishing reaction was carried out at a reaction temperature of 350 ℃, a hydrogen partial pressure of 10MPaG and a volume space velocity of 0.5h^-1The hydrogen-oil ratio (v/v) was 800, and the results of analysis of the product oil are shown in Table 9.

TABLE 9

Comparative example 3

Hydrofinishing was carried out in accordance with the procedure of example 1, except that the first stage removal of impurities was not carried out, and the first stage hydrofinishing reaction product was directly subjected to the second stage hydrofinishing reaction, and the analytical results of the product oil are shown in Table 10.

Watch 10

From the above examples, it can be seen that the present invention can effectively reduce the sulfur content and nitrogen content of non-petrochemical naphtha, such as coal-based naphtha, and solve the problem of high value-added utilization of non-petrochemical naphtha. In particular, comparing example 1 with comparative examples 1-3, it can be seen that only the process according to the invention is effective in reducing the sulfur content and nitrogen content of non-petrochemical naphthas.

The preferred embodiments of the present invention have been described in detail, however, the present invention is not limited to the specific details of the above embodiments, and various simple modifications may be made to the technical solution of the present invention within the technical idea of the present invention, and these simple modifications are within the protective scope of the present invention.

It should be noted that the various technical features described in the above embodiments can be combined in any suitable manner without contradiction, and the invention is not described in any way for the possible combinations in order to avoid unnecessary repetition.

In addition, any combination of the various embodiments of the present invention is also possible, and the same should be considered as the disclosure of the present invention as long as it does not depart from the spirit of the present invention.

Claims

1. A method for producing catalytic reforming raw materials by hydrofining non-petrochemical naphtha comprises the following steps: carrying out a first-stage hydrofining reaction on non-petrochemical naphtha, carrying out first-stage impurity removal on a product of the first-stage hydrofining reaction, and carrying out a second-stage hydrofining reaction on a residual reaction product material subjected to the first-stage impurity removal;

wherein the first-stage hydrofining reaction conditions comprise: the temperature is 280-380 ℃, the hydrogen partial pressure is 2-8MPaG, the volume space velocity is 1-8h^-1The volume ratio of hydrogen to oil is 100-600; the two-stage hydrofining reaction conditions comprise: the temperature is 300-390 ℃, the hydrogen partial pressure is 2-8MPaG, the volume space velocity is 1-8h^-1The volume ratio of hydrogen to oil is 100-600;

the first-stage impurity removal enables the sulfur content in the residual reaction product material after the first-stage impurity removal to be reduced to below 30 mu g/g and the nitrogen content to be reduced to below 5 mu g/g.

2. The process of claim 1, wherein the first stage hydrofinishing reaction conditions comprise: the temperature is 320-340 ℃, the hydrogen partial pressure is 2.5-4.5MPaG, and the volume space velocity is 2-6h^-1The volume ratio of hydrogen to oil is 180-;

and/or, the second-stage hydrofinishing reaction conditions comprise: the temperature is 320-340 ℃, the hydrogen partial pressure is 2.7-4.5MPaG, and the volume space velocity is 2-6h^-1The volume ratio of hydrogen to oil is 180-400.

3. The method of claim 1 or 2, wherein the first stage dehiscence means is: mixing the product of the first-stage hydrofining reaction with water, and then carrying out gas-oil-water three-phase separation, so that the first-stage oil phase obtained by gas-oil-water three-phase separation is subjected to evaporation separation, thereby further separating hydrogen sulfide and ammonia gas.

4. The process of claim 3, wherein the product of the first stage hydrofinishing reaction is mixed with water in a ratio of 100: 2-5 weight ratio; and/or the presence of a gas in the gas,

the gas-oil-water three-phase separation conditions comprise: the temperature is 15-60 ℃, and the pressure is 0.1-0.4MPaG lower than the hydrogen partial pressure of the first-stage hydrofining reaction; and/or the presence of a gas in the gas,

the evaporation separation conditions include: the temperature is 150 ℃ and 230 ℃, and the pressure is 0.8-1.5 MPaG.

5. The method of claim 1, further comprising: and (3) performing second-stage impurity removal and/or fractionation on a product of the second-stage hydrofining reaction, wherein the second-stage impurity removal enables the sulfur content of the residual reaction product material subjected to the second-stage impurity removal to be reduced to below 0.5 mu g/g and the nitrogen content to be reduced to below 0.5 mu g/g.

6. The method of claim 5, wherein the second stage of dehiscence is: and mixing the second-stage hydrofining reaction product with water, and then carrying out gas-oil-water three-phase separation, so that a second-stage oil phase obtained by gas-oil-water three-phase separation is subjected to evaporation separation to further separate hydrogen sulfide and ammonia gas.

7. The process of claim 6, wherein the second-stage hydrofinishing reaction product is mixed with water in a ratio of 100: 2-5 weight ratio; and/or the presence of a gas in the gas,

the gas-oil-water three-phase separation conditions comprise: the temperature is 15-60 ℃, and the pressure is 0.1-0.4MPaG lower than the hydrogen partial pressure of the two-stage hydrofining reaction; and/or the presence of a gas in the gas,

the evaporation separation conditions include: the temperature is 180 ℃ and 260 ℃, and the pressure is 0.8-1.8 MPaG.

8. The method of claim 3, further comprising: and taking the gas phase collected by gas-oil-water three-phase separation as a hydrogen source to provide hydrogen for the first-stage hydrofining reaction, and controlling the content of hydrogen sulfide and the content of ammonia in the hydrogen source for providing hydrogen for the second-stage hydrofining reaction to be below 0.05 volume percent and below 0.01 volume percent.

9. The process of claim 1 wherein the first stage hydrofinishing reaction product is preheated prior to heat exchange with the newly introduced non-petrochemical naphtha-containing feed.

10. The process of claim 1, wherein the first-stage hydrofinishing reaction and/or the second-stage hydrofinishing reaction is carried out in an upflow fixed bed reactor.

11. The process according to any one of claims 1-2 and 4-10, wherein the non-petrochemical naphtha is a naphtha fraction having a boiling range between 60 ℃ and 150 ℃, a sulfur content of 600 μ g/g or more and a nitrogen content of 500 μ g/g or more.

12. The method according to claim 3, wherein the non-petrochemical naphtha is a naphtha fraction having a boiling range of 60 to 150 ℃, a sulfur content of 600 μ g/g or more and a nitrogen content of 500 μ g/g or more.

13. The method of claim 11, wherein the non-petrochemical naphtha is at least one of a direct liquefaction oil of coal and/or biomass, an indirect liquefaction oil of coal and/or biomass, and a pyrolysis oil of coal and/or biomass.

14. The method of claim 12, wherein the non-petrochemical naphtha is at least one of a direct liquefaction oil of coal and/or biomass, an indirect liquefaction oil of coal and/or biomass, and a pyrolysis oil of coal and/or biomass.

15. A method for producing catalytic reforming raw materials by hydrofining non-petrochemical naphtha comprises the following steps:

(1) continuously introducing non-petrochemical naphtha into a first hydrofining reactor to perform a first-stage hydrofining reaction, wherein the first-stage hydrofining reaction conditions comprise: the temperature is 280-380 ℃, the hydrogen partial pressure is 2-8MPaG, the volume space velocity is 1-8h^-1The volume ratio of hydrogen to oil is 100-600;

(2) preheating a first-stage hydrofining reaction product, and then exchanging heat with the newly introduced material containing non-petrochemical naphtha in the step (1);

(4) introducing the residual reaction product material after the first-stage impurity removal into a second-stage hydrofining reactor to carry out second-stage hydrofining reaction, wherein the second-stage hydrofining reaction conditions comprise: the temperature is 300-390 ℃, the hydrogen partial pressure is 2-8MPaG, the volume space velocity is 1-8h^-1The volume ratio of hydrogen to oil is 100-600;

(5) and (3) carrying out second-stage impurity removal on the second-stage hydrofining reaction product, so that the sulfur content in the residual reaction product material subjected to second-stage impurity removal is reduced to be below 0.5 mu g/g and the nitrogen content is reduced to be below 0.5 mu g/g, wherein the second-stage impurity removal mode is as follows: mixing the second-stage hydrofining reaction product with water, and then carrying out gas-oil-water three-phase separation, so that a second-stage oil phase obtained by gas-oil-water three-phase separation is subjected to evaporation separation to further separate hydrogen sulfide and ammonia gas;

wherein the non-petrochemical naphtha is naphtha fraction with distillation range of 60-150 ℃, sulfur content is above 600 mu g/g and nitrogen content is above 500 mu g/g; the first-stage hydrofining reactor and/or the second-stage hydrofining reactor is an up-flow fixed bed reactor.

16. The method of claim 15, wherein the first stage hydrofinishing reaction conditions comprise: the temperature is 320-340 ℃, the hydrogen partial pressure is 2.5-4.5MPaG, and the volume space velocity is 2-6h^-1The volume ratio of hydrogen to oil is 180-;

17. The method of claim 1, wherein the reaction unit for producing a catalytic reforming feedstock by hydrofinishing a non-petrochemical naphtha comprises a first stage hydrofinishing reactor, a first stage impurity removal unit and a second stage hydrofinishing reactor,

the first-stage hydrofining reactor and the second-stage hydrofining reactor respectively comprise a catalyst bed layer, a material inlet and a material outlet; the material outlet of the first-stage hydrofining reactor is connected with the material inlet of the second-stage hydrofining reactor through a first-stage impurity removing unit; the first stage impurity removal unit is used for reducing the sulfur content and the nitrogen content in the material from the material outlet of the first stage hydrofining reactor.

18. The method of claim 17, wherein the first stage impurity removal unit comprises a gas-oil-water three-phase separator and a stabilizer column which are sequentially connected with a material outlet of the first stage hydrofining reactor, an oil phase outlet of the gas-oil-water three-phase separator is connected with a material inlet of the stabilizer column, and a material outlet of the stabilizer column is connected with a material inlet of the second stage hydrofining reactor.

19. The process of claim 17, further comprising a second stage dehazing unit coupled to the feed outlet of the second stage hydrofinishing reactor for reducing the sulfur content and nitrogen content of the feed from the feed outlet of the second stage hydrofinishing reactor and/or a fractionation column.

20. The method of claim 19, wherein the second-stage impurity removal unit comprises a gas-oil-water three-phase separator and a stabilizer column which are sequentially connected with a material outlet of the second-stage hydrofining reactor, an oil phase outlet of the gas-oil-water three-phase separator is connected with a material inlet of the stabilizer column, and/or a material outlet of the stabilizer column is connected with a material inlet of the fractionating column.

21. The process of claim 18, wherein the gas phase outlet of the gas-oil-water three-phase separator is connected to the feed inlet of the first stage hydrofinishing reactor.

22. The method of claim 17, wherein the first hydrofining reactor is connected with a heating unit, the heating unit comprises a heating furnace and a heat exchanger, one end of the heating furnace is connected with the material outlet of the first hydrofining reactor, the other end of the heating furnace is connected with the heat exchanger, the heating furnace is used for preheating the material from the material outlet of the first hydrofining reactor, and the heat exchanger is used for exchanging heat between the material preheated by the heating furnace and the starting material before entering the first hydrofining reactor, so that the heated starting material is sent into the first hydrofining reactor.

23. The process of any one of claims 17-22, wherein in the first stage hydrofinishing reactor and/or the second stage hydrofinishing reactor, the feed inlet is located at the bottom of the hydrofinishing reactor and the feed outlet is located at the top of the hydrofinishing reactor.

24. The process of claim 23, wherein the first-stage hydrofinishing reactor and/or the second-stage hydrofinishing reactor is an upflow fixed bed reactor.