JP2007238832A - Method for treating natural gas condensate and system for treating the same - Google Patents

Abstract

<P>PROBLEM TO BE SOLVED: To provide an efficient, easily operable and low cost treatment method for separating and refining a natural gas condensate (NGL) produced in a natural gas production process into an LPG fraction, a light naphtha fraction, a heavy naphtha fraction, a kerosene fraction, a gas oil fraction, and the like. <P>SOLUTION: NGL is preliminarily treated to remove impurities contained in the NGL. The impurities-removed NGL is collectively subjected to a hydrodesulfurization treatment, and then distilled to separate into an LPG fraction, a light naphtha fraction, a heavy naphtha fraction, a kerosene fraction, and a gas oil fraction. In the preliminary treatment, salts contained in NGL are removed by a desalting treatment 21 and the dehydrating treatment 22, and the residues are then subjected to a mercury-removing treatment 23 to remove mercury largely contained in NGL. In the distillation treatment, the impurities-removed NGL is first subjected to an atmospheric distillation treatment 40 to separate into a gas component containing an LPG fraction and a naphtha fraction, a kerosene fraction, and a gas oil fraction. The gas component is further separated into an LPG fraction, a light naphtha fraction and a heavy naphtha fraction. <P>COPYRIGHT: (C)2007,JPO&INPIT

Description

  The present invention relates to a liquefied petroleum gas (hereinafter referred to as LPG), light naphtha, heavy naphtha, from natural gas condensate (hereinafter referred to as NGL) which is a liquid component accompanying the natural gas at the time of sampling in a natural gas sampling plant. The present invention relates to an NGL processing method and a processing system for manufacturing products such as kerosene and light oil.

NGL recovered along with natural gas at a natural gas production plant contains LPG, light naphtha, heavy naphtha, kerosene, light oil, residual oil fraction, etc., and is an important natural resource. . In particular, the content of low-boiling fractions is significantly higher than that of crude oil, and occupies a large role in the production of LPG, naphtha, kerosene, and light oil. For example, looking at the general properties of NGL and crude oil, the fraction of light gas combined with LPG is about 0 to 15% for NGL, but 5% or less for crude oil. On the other hand, the residual oil fraction, which is a heavy component, is 45 to 65% in crude oil, whereas the abundance in NGL is 5% or less. In particular, NGL is characterized by a very high naphtha content of 30 to 90%, which is a raw material for gasoline and petrochemical products.
In particular, as a measure for preventing global warming, in recent years, natural gas with a small amount of carbon dioxide generated per unit of generated energy has attracted much attention, and its development has become active. Along with this, the amount of NGL produced along with it tends to increase. As described above, since NGL has many low-boiling components, it has excellent characteristics as a raw material for the various petroleum refined products, and a technique for efficiently separating and refining this NGL has become important.

The following methods are known as methods for separating and refining NGL into various petroleum fractions. One of them is a method in which NGL is mixed with crude oil and processed in accordance with the separation and purification of crude oil to obtain products of each fraction. FIG. 3 shows the schematic process. In this method, NGL as a raw material is processed by a normal crude oil processing method. That is, NGL 1 is mixed with crude oil 13, desalted by desalting apparatus 21, and then sent to atmospheric distillation tower 40 to be separated into light gas components such as naphtha, kerosene fraction, light oil fraction, and heavy oil fraction. . The light gas component is further separated into an LPG component and a naphtha fraction by a stabilizer 50, and the naphtha fraction is further separated into a light naphtha fraction and a heavy naphtha fraction by a naphtha fractionation tower 51. Among the fractions separated by distillation, the liquid phase fractions are hydrodesulfurized by hydrodesulfurization units (301, 302, 303, 304), respectively, and converted to products with low sulfur content. The gas component is subjected to vapor phase desulfurization treatment, while the LPG fraction is subjected to two-stage cleaning of an amine cleaning device 52 that removes hydrogen sulfide and a soda cleaning device 53 that removes a mercaptan component.
When crude oil cannot be used, the same processing as when NGL alone is mixed with the crude oil of FIG. 3 can be performed. The processing flow in this case is the same as in the case where there is no supply line for the crude oil 13 in FIG.

In the above method, since desulfurization is performed after NGL is separated into each fraction by atmospheric distillation, it is necessary to provide a hydrodesulfurization device for each fraction in order to remove the sulfur content in the product. The cost associated with the operation and equipment is increased. As a countermeasure, a method has been proposed in which an LPG fraction is removed from NGL by a predistillation tower (prefractionator), hydrodesulfurization treatment is performed, and then distillation separation is performed. FIG. 4 shows the schematic process. In this method, NGL 1 is sent to the preliminary distillation column 41 after being desalted by the desalting apparatus 21. Here, although the gas component containing LPG is extracted from the top of the preliminary distillation column 41, the light naphtha is subsequently recovered by the stabilizer. The LPG from which the light naphtha is removed by the stabilizer 42 is subjected to removal of the sulfur by the amine cleaning device 52 and the soda cleaning device 53 as in FIG.
The light naphtha recovered from the stabilizer 42 and the liquid phase component of the preliminary distillation column 41 are sent together to the hydrodesulfurization apparatus 30, hydrodesulfurized, and then sent to the atmospheric distillation column 40. The components are separated into a gas component mainly composed of naphtha, a kerosene fraction 9 and a light oil fraction 10 in the atmospheric distillation tower 40. A gas component mainly composed of naphtha is separated into LPG 7, light naphtha fraction 8, and heavy naphtha fraction 9 by a stabilizer 50 and a naphtha fractionation tower 51. In this case, since hydrodesulfurization has already been performed before atmospheric distillation, it is not necessary to provide a hydrodesulfurization apparatus individually for each fraction after atmospheric distillation.
In the above method, hydrodesulfurization treatment is performed after NGL is predistilled, but a method of hydrodesulfurizing all raw materials without predistillation and then separating them by atmospheric distillation has been proposed as a crude oil treatment method. (Patent Documents 1 and 2). That is, Patent Document 1 proposes a catalyst suitable for the above treatment, and Patent Document 2 proposes a method of further treating heavy components by distillation after hydrodesulfurization of crude oil.
On the other hand, NGL is characterized by a high mercury content in addition to the characteristic that it contains a lot of light hydrocarbons. When using a product fraction such as naphtha separated and produced from NGL as a raw material for petrochemical products, this mercury needs to be removed at the separation and production stage because it may poison the catalyst (Patent Document 3). . This mercury removal is usually carried out for each fraction, as in the hydrodesulfurization treatment, and the mercury removal agent used therefor is a solid acid (Patent Document 3), a metal sulfide such as molybdenum (Patent Document) 4) have been proposed, most of which are related to the mercury removal agent or mercury removal method itself. In connection with the separation and purification of NGL, light carbonization with a boiling point of 100 ° C. or lower by distillation. Only a method of separating a hydrogen fraction and removing mercury from this light hydrocarbon fraction (Patent Document 5) and a method of removing mercury after removing a mercaptan (Patent Document 6) have been proposed. That is, as for the separation and purification of NGL, the separation and purification technology of crude oil is applied, and the technology based on the characteristics of the NGL is currently limited to the removal technology of mercury and the like.

Japanese Patent No. 3669377 Japanese Patent Laid-Open No. 2003-49175 JP-A-2-2699797 Japanese Examined Patent Publication No. 7-103377 Japanese Patent Laid-Open No. 11-181447 JP-A-6-9965

In this way, NGL is separated and refined based on crude oil separation and purification technology, considering the above-mentioned NGL characteristics (high light fraction content and high mercury content). The NGL separation and purification system has not been studied.
If separation and refining of NGL can be mixed with existing crude oil and processed in the crude oil separation and refining system, it can be processed without burdening too much equipment, but this method can be used when crude oil production facilities do not coexist. It cannot be adopted. That is, a separation and purification technique using NGL alone is necessary.
As shown in FIG. 3, the method of hydrodesulfurizing NGL alone by distillation as shown in FIG. 3 requires refining equipment for each fraction, and as described above, the burden on equipment and operation is large. When hydrodesulfurization is performed after separating LPG by preliminary distillation (FIG. 4), it is not necessary to provide hydrodesulfurization equipment for each fraction, but a preliminary distillation column is required. In addition, since the mercaptan component shifts to the LPG component without being hydrogenated, there is a problem that a two-stage desulfurization device of an amine cleaning device for removing hydrogen sulfide and a soda cleaning device for removing mercaptan is necessary.
In order to deal with such problems, a method for distilling raw materials after hydrodesulfurization has been proposed for crude oil. However, since crude oil and NGL have different characteristics as described above, they cannot be applied as they are. That is, if NGL is applied as it is, almost all of the supplied NGL is gasified at the hydrodesulfurization heater outlet. As a result, solidified components such as metals are deposited on the inner surface of the heating tube, and impurities existing in the NGL are likely to be deposited, and abnormal heating of the heating tube is likely to occur. This is a phenomenon that cannot occur with crude oil containing around 50% heavy.
Further, a mercury treatment method suitable for separation and purification of NGL is also desired for mercury contained in a large amount in NGL.
The present invention has been made to solve the above technical problems, and an object of the present invention is to efficiently process NGL in consideration of the characteristics of NGL for separating and purifying NGL into individual fractions. It is to provide a method and a processing system.

  According to a first aspect of the present invention, in the NGL treatment method for separating and purifying NGL into products of each fraction, hydrodesulfurization treatment is performed after the NGL is desalted and then hydrodesulfurized NGL is further added. It is separated and purified by distillation separation into LPG, light naphtha fraction, heavy naphtha fraction, kerosene fraction, and light oil fraction.

According to a second aspect of the present invention, in the first aspect, the demineralized NGL is subjected to a dehydration treatment before the hydrodesulfurization treatment.

According to a third aspect of the present invention, in the second aspect, the desalted NGL is cooled before dehydration.

According to a fourth aspect of the present invention, in the second and third aspects, the mercury-containing NGL is dehydrated and then demercured, and then the hydrodesulfurization is performed.

According to a fifth invention of the present invention, in the first to fourth inventions, in the hydrodesulfurization treatment, a reaction product containing hydrodesulfurized NGL and hydrogen is applied at a pressure of 4.5 to 8 MPa, a temperature of 25 to 25. Gas-liquid separation is performed under the condition of 50 ° C. to separate into a gas phase component mainly composed of hydrogen and a liquid phase component mainly composed of hydrodesulfurized NGL.

According to a sixth aspect of the present invention, in the fifth aspect, the gas phase component containing hydrogen as a main component separated by the gas-liquid separation is washed with an absorbing solution having hydrogen sulfide absorption performance, and the gas phase is After removing the hydrogen sulfide contained in the components, the pressure is increased and reused for hydrodesulfurization treatment.

According to a seventh aspect of the present invention, in the fifth aspect, a light gas component containing LPG and a naphtha fraction obtained by distilling the liquid phase component mainly composed of the hydrodesulfurized NGL, a kerosene fraction, A light oil fraction is separated, and the light gas component is further separated into LPG, a light naphtha fraction, and a heavy naphtha fraction.

The eighth invention of the present invention is a demineralizer for removing salt from an NGL by a NGL treatment system, a hydrodesulfurization apparatus for desulfurizing NGL from the demineralizer with a catalyst in the presence of hydrogen, and a hydrodesulfurization apparatus. The gas-liquid separation device of the product from, the gas phase component separated by the gas-liquid separation device is desulfurized and then recycled to the hydrodesulfurization device, and the liquid phase component separated by the gas-liquid separation device is LPG And a distillation purification apparatus for separating and purifying light naphtha fraction, heavy naphtha fraction, kerosene fraction and light oil fraction.

  According to a ninth aspect of the present invention, in the eighth aspect, a dehydrator is provided between the demineralizer and the hydrodesulfurizer.

  According to a tenth aspect of the present invention, in the ninth aspect, a cooling device for cooling NGL is provided between the desalting device and the dehydrating device.

  An eleventh aspect of the present invention is characterized in that, in the ninth and tenth aspects, a demercuring device is provided between the dehydrating device and the hydrodesulfurization device.

According to a twelfth aspect of the present invention, in the eighth to eleventh aspects, the distillation purification apparatus includes a light gas component containing hydrodesulfurized NGL containing LPG and a naphtha fraction, a kerosene fraction and a light oil fraction. An atmospheric distillation apparatus for separating the light gas component into a naphtha fraction and an LPG, and a naphtha fractionation tower for separating the naphtha fraction into a light naphtha fraction and a heavy naphtha fraction. To do.

According to the present invention, since mercury removal and hydrodesulfurization are performed not for each fraction but for NGL before distillation separation, there is no need to provide a mercury removal apparatus and a hydrodesulfurization apparatus for each fraction. In addition, efficient processing can be performed in terms of equipment, operation, and energy.
In addition, since a pre-distilling column is not required and hydrodesulfurization treatment including LPG can be performed, mercaptan is also converted into hydrogen sulfide in the hydrodesulfurization process, so there is no need to remove mercaptan from LPG by a soda washing device. The cleaning device can be omitted.
By performing desalting, dehydration, and mercury removal in the pretreatment, even if hydrodesulfurization treatment is performed without separating NGL by distillation, heating tube breakage due to accumulation of salt, contaminants, mercury, etc. in the heater heating tube, Troubles such as mercury accumulation in reactors, heat exchangers, containers, etc. and maintenance work corresponding thereto are greatly reduced, and stable operation becomes possible. Further, by performing the desulfurization treatment collectively after the pretreatment step, not only the salinity, impurities, and mercury but also sulfur is almost eliminated after the distillation apparatus, and the corrosion of the equipment due to the sulfide can be significantly reduced.
Furthermore, since a dehydrating device is provided in front of the demercuring device, a remover that lowers the demercuring performance when water is present, such as activated carbon, can be used without fear of performance degradation.

  Hereinafter, the present invention will be described in detail with reference to the drawings. Note that the present invention is not limited to the embodiments. In addition, constituent elements in the following embodiments include those that can be easily assumed by those skilled in the art or those that are substantially the same.

An embodiment of an NGL processing method according to the present invention will be described with reference to FIGS. FIG. 1 is a flowchart showing the NGL processing method according to the present invention. In FIG. 1, NGL1, which is a raw material, is first sent to a pretreatment step 20, where impurities contained in NGL are removed. The impurities to be removed here are impurities that may be deposited in the heating pipe of the heater in the downstream hydrodesulfurization reaction step such as salts and metals, and include salts and mercury.
The pretreatment process 20 includes three steps of a desalting apparatus 21, a dehydrating apparatus 22, and a mercury removing apparatus 23. That is, since salt and mercury are problems in the downstream hydrodesulfurization reaction step, the salt is first removed by the demineralizer 21. As this desalinization apparatus 21, what is normally used with crude oil or a NGL refinement | purification equipment can be used. The NGL from which the salt content has been removed by the desalting apparatus 21 still contains free water, so that 0.5 to 10 ppm (weight) remains in a form in which the salt content is dissolved in the free water. Since it is necessary to remove salts dissolved in the free water as much as possible for the stable treatment in the downstream, the NGL discharged from the desalting apparatus 21 is further dehydrated by the dehydrating apparatus 22 to remove the free water. Remove. At this time, in order to improve the removal performance, the NGL at a temperature of 50 to 120 ° C. coming out from the desalting apparatus 21 is cooled, and in addition to the original free water, the water dissolved in the NGL is also precipitated as free water. . As a level of this cooling, it is preferable to cool so that the temperature is lowered by 20 ° C. or more (the temperature after cooling is 15 to 100 ° C.) if possible. The free water thus generated by cooling and the original free water are then dehydrated and removed by the prefilter or coalescer together with the salt and impurities dissolved in the dehydrator 22.
The NGL dehydrated by the dehydrator 22 further enters the mercury removal apparatus 23 to remove mercury in the NGL. This mercury removal apparatus can use the method shown in the above patent document. In the method of the present invention, since the dehydration treatment is performed before the mercury removal treatment, there is an effect that a remover that can reduce the mercury removal performance when free water such as activated carbon is present can be used without any problem.
The configuration of the pretreatment process is determined in consideration of the properties of the NGL to be processed, the operation method of the equipment, and the like. In the present invention, since hydrodesulfurization is performed before NGL is separated by distillation, removal of salt is essential. This is because if salt remains as described above, it accumulates on the heating tube and causes troubles such as breakage. In the case where the salt content in the NGL can be reduced to some extent by using only a desalting apparatus with a small amount of salt, the desalinating apparatus alone can be used. In the case where the salt content in the NGL remains significantly only with the desalination apparatus, or when it is desired to increase the reliability of operation and maintenance, it is desirable to further reduce the salt content by installing a dehydrator. The effect can be further increased by cooling before dehydration.
When NGL contains mercury, it is desirable to install it after the dehydrator and before the hydrodesulfurizer as described above. As described above, mercury is required to be removed at any stage of the NGL treatment because each product fraction may become a catalyst poison when used in other treatment processes. In this invention, by processing before hydrodesulfurization, it can process collectively and can also prevent the trouble by precipitation of mercury in a downstream apparatus. If NGL does not contain mercury, or if it is contained, the amount is small, and if it does not reach the level that it becomes a catalyst poison or affects downstream equipment, the mercury removal process is unnecessary. is there.

The NGL 2 from which salt, impurities, mercury and the like that have exited the mercury removal apparatus 23 have been removed is then sent to the hydrodesulfurization process 30. An example of the processing flow of the hydrodesulfurization reaction step 30 will be described with reference to FIG. The NGL 2 from which impurities are removed in the pretreatment step 20 is sent to the heater 31 together with the supplementary hydrogen 14 and the recycled hydrogen 15. Since NGL contains a lot of light fractions as described above, the reaction temperature of the hydrodesulfurization reactor 32 can be set lower than the reaction temperature at the time of hydrodesulfurization of kerosene oil, but still about 250 to 360 ° C. is necessary. On the other hand, since NGL is almost entirely gasified at about 300 ° C., there is almost no liquid phase in the heater 31 as described above. However, in the present invention, this gas is removed because impurities are removed by pretreatment. As described above, the accumulation of impurities in the heater 31 due to the conversion can be prevented.
The NGL heated together with hydrogen to the temperature required for the reaction of the hydrodesulfurization reactor 32 by the heater 31 is sent to the hydrodesulfurization reactor 32, and sulfur in the hydrodesulfurization reactor 32 in the presence of hydrogen and a catalyst. The portion is converted to hydrogen sulfide and desulfurized. Here, there is no restriction | limiting in particular in the catalyst, reactor, etc. which are used, A well-known desulfurization reactor and a desulfurization catalyst can be used.
The reaction product containing desulfurized NGL and hydrogen that has exited the hydrodesulfurization reactor 32 is heat-exchanged with a fluid containing NGL and hydrogen before desulfurization in the heat exchanger 33, and then cooled, and then, an air cooling device 34 and a water cooling device 35 And is sent to the gas-liquid separator 36.

As operating conditions of the gas-liquid separator 36, a pressure of 4.5 to 8 MPa and a temperature of 25 to 50 ° C. are selected. In the present invention, unlike the conventional method shown in FIG. 4, the hydrodesulfurization treatment is performed collectively without separating the LPG. As a result, since the LPG component is also included in the hydrodesulfurization reaction product, when the operating condition of the gas-liquid separator 36 becomes higher than the set temperature or falls below the set pressure, the LPG component is transferred to the gas-liquid separator 36. The amount transferred to the gas phase side increases. As the amount of LPG transferred to the gas phase increases, the hydrogen concentration in the gas phase decreases relatively, and the reaction pressure needs to be increased in order to maintain the hydrogen pressure necessary for the hydrodesulfurization reaction. In the above operating conditions, there is almost no influence. In addition, even when LPG is collectively processed, the amount of hydrogen dissolved in the liquid phase is very small and within an allowable range. Table 1 shows examples of the gas phase hydrogen concentration and the liquid phase dissolved hydrogen amount when the operating conditions of the gas-liquid separator are a temperature of 40 ° C. and a pressure of 4.69 MPa.

The gas phase component 16 separated by the gas-liquid separator 36 removes the hydrogen sulfide generated by the hydrodesulfurization reactor 32 by the hydrogen sulfide removal device 37, and then the pressure is increased by the recycle gas compressor 38 to supply hydrogen for supplementary supply. It is circulated to the hydrodesulfurization reactor together with the supplementary hydrogen that has been pressurized by the compressor 39.
On the other hand, the NGL component is extracted from the gas-liquid separator 36 as the liquid phase 3 and sent to the atmospheric distillation apparatus 40.

In FIG. 1, the desulfurized NGL component 3 output from the hydrodesulfurization reaction step 30 is sent to the atmospheric distillation unit 40 and is distilled and separated at an atmospheric pressure (atmospheric pressure) of 0 to 0.1 MPaG. As a result, the gas component 4 including the LPG fraction and the naphtha fraction is extracted from the top of the atmospheric distillation apparatus 40, the kerosene fraction 10 is extracted from the upper stage, and the light oil fraction 11 is extracted from the middle stage. Since NGL has a small heavy content and is hydrodesulfurized, almost no heavy oil fraction 12 is produced from the atmospheric distillation apparatus 40, but the heavy content of NGL is relatively high, and the heavy oil fraction Is extracted from the bottom of the tower.
The gas component 4 containing the LPG fraction and the naphtha fraction extracted from the top of the atmospheric distillation apparatus 40 is then sent to the stabilizer 50 and separated into the LPG fraction 5 and the naphtha fraction 6. The temperature of the gas component 4 extracted from the top of the atmospheric distillation apparatus tower is 80 to 120 ° C. The stabilizer 50 is normally operated at a pressure of about 0.5 to 1.5 MPaG, and the temperature of the LPG fraction extracted from the top of the tower of the stabilizer 50 is 50 to 100 ° C. The LPG fraction 5 contains hydrogen sulfide that has been dissolved in the liquid phase without being separated by the gas-liquid separator 36 in the hydrodesulfurization reaction step 30. Remove to obtain product LPG fraction 7.
On the other hand, the naphtha fraction at 150 to 200 ° C. extracted from the bottom of the stabilizer 50 is further separated into a light naphtha fraction 8 and a heavy naphtha fraction 9 by the naphtha fractionation tower 51. The operating pressure of this naphtha fractionation tower is about 0 to 0.3 MPaG. If it is not necessary to separate the naphtha into light and heavy naphtha, this naphtha fractionation tower can be omitted.
As described above, according to the present invention, in the hydrodesulfurization reaction step 30, except for removing hydrogen sulfide dissolved in the liquid phase, a desulfurization device and a demercury device are provided on the downstream side of the hydrodesulfurization step 30. There is no need to provide.
If NGL contains a large amount of heavy components, the cost of demercuring after dehydration may increase. In such a case, since there is a heavy component, the risk of almost no liquid phase in the heater is reduced, so dehydration can be performed, and the mercury removal operation can be performed for each individual fraction. .

  As described above, according to the present invention, since natural gas condensate (NGL) can be processed by an efficient separation and purification method considering its characteristics, petroleum products such as LPG, naphtha, and kerosene are used from NGL. This makes it possible to provide petrochemical raw materials at a low cost.

The flowchart which shows the Example of the processing method of NGL of this invention The flowchart which shows the example of the processing method of the hydrodesulfurization reaction process used for the NGL processing equipment of this invention Flow chart showing conventional NGL processing method Another flow chart showing a conventional NGL processing method

Explanation of symbols

1 Raw material natural gas condensate (NGL)
2 NGL with pretreatment
3 Hydrodesulfurization reaction product from the hydrodesulfurization process 4 Gas component extracted from the top of the atmospheric distillation tower 5 Gas component at the outlet of the stabilizer 6
Stabilizer outlet liquid component 7 LPG fraction 8 Light naphtha fraction 9 Heavy naphtha fraction 10 Kerosene fraction 11 Light oil fraction 12 Heavy oil fraction 13 Crude oil 14 Supplementary hydrogen 15, 16 Recycled hydrogen-containing gas 20 Pretreatment process 21 Detreatment Salt device 22 Dehydration device 23 Demercury device 30, 301, 302, 303, 304 Hydrodesulfurization reaction step 31 Heater 32 Hydrodesulfurization reactor 33 Heat exchanger 34 Air cooling device 35 Water cooling device 36 Gas-liquid separator 37 Hydrogen sulfide 37 Removal equipment 38, 39 Hydrogen compressor 40 Atmospheric distillation equipment 41 Preliminary distillation tower 42, 50 Stabilizer 51 Naphtha fractionation tower 52 Amine washing equipment 53 Soda washing equipment 54 Desulfurization equipment

Claims (12)

  In the natural gas condensate treatment method in which natural gas condensate is separated and purified into products of each fraction, the natural gas condensate is demineralized and then hydrodesulfurized, and the hydrodesulfurized natural gas condensate is further distilled. A method for treating natural gas condensate, which is separated and refined into liquefied petroleum gas, light naphtha fraction, heavy naphtha fraction, kerosene fraction, and light oil fraction.   2. The natural gas condensate treatment method according to claim 1, wherein the demineralized natural gas condensate is dehydrated before the hydrodesulfurization treatment.   3. The natural gas condensate treatment method according to claim 2, wherein the desalted natural gas condensate is cooled before dehydration.   4. The method for treating natural gas condensate according to claim 2, wherein the mercury-containing natural gas condensate is demerged and then demercured, and then the hydrodesulfurization treatment is performed. In the hydrodesulfurization treatment, a reaction product containing hydrodesulfurized natural gas condensate and hydrogen is subjected to gas-liquid separation under conditions of pressure 4.5 to 8 MPa and temperature 25 to 50 ° C. 5. The method for treating a natural gas condensate according to claim 1, wherein the gas phase component is separated into a liquid phase component mainly composed of hydrodesulfurized natural gas condensate.   The gas phase component mainly composed of hydrogen separated by the gas-liquid separation is washed with an absorption liquid having hydrogen sulfide absorption performance to remove hydrogen sulfide contained in the gas phase component, and then pressurized to hydrogenate. The method for treating natural gas condensate according to claim 5, wherein the method is used again for desulfurization treatment.   The liquid phase component mainly composed of the hydrodesulfurized natural gas condensate is separated by distillation into a light gas component containing a liquefied petroleum gas and a naphtha fraction, a kerosene fraction and a light oil fraction, 6. The method for treating natural gas condensate according to claim 5, wherein the gas component is further separated into a liquefied petroleum gas, a light naphtha fraction, and a heavy naphtha fraction.   A demineralizer for removing salt from natural gas condensate, a hydrodesulfurization treatment apparatus for desulfurizing natural gas condensate from the demineralizer with a catalyst in the presence of hydrogen, a gas-liquid separation apparatus for products from the hydrodesulfurization apparatus, A hydrogen recycling device that desulfurizes the gas phase components separated by the gas-liquid separation device and then recycles them to the hydrodesulfurization device. The liquid phase components separated by the gas-liquid separation device are liquefied petroleum gas, light naphtha fraction, heavy A natural gas condensate treatment system comprising a distillation purification apparatus for separating and purifying into a naphtha fraction, a kerosene fraction and a light oil fraction.   The natural gas condensate treatment system according to claim 8, wherein a dehydrator is provided between the desalinator and the hydrodesulfurizer.   The natural gas condensate treatment system according to claim 9, wherein a cooling device for cooling the natural gas condensate is provided between the desalting apparatus and the dehydrating apparatus.   The natural gas condensate treatment system according to claim 9, wherein a demercury apparatus is provided between the dehydration apparatus and the hydrodesulfurization apparatus.   The distillation purification apparatus includes a light gas component containing a liquefied petroleum gas and a naphtha fraction, a normal pressure distillation apparatus that separates the hydrodesulfurized natural gas condensate into a kerosene fraction and a light oil fraction, and the light gas component is separated into a naphtha. The natural gas condensate according to any one of claims 8 to 11, comprising a stabilizer for separating the naphtha fraction into a light naphtha fraction and a heavy naphtha fraction. Processing system.

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