JP2009040844A - Method for producing reformed crude oil - Google Patents

Abstract

<P>PROBLEM TO BE SOLVED: To provide a method for producing a reformed crude oil for efficiently improving quality of a low-quality crude oil. <P>SOLUTION: The method for producing a reformed crude oil comprises: a step of separating a naphtha fraction from a crude oil to produce a topped crude oil (a naphtha fraction separation step); a step of hydrogenating the topped crude oil (a topped crude oil hydrogenation step); and a step of utilizing the naphtha fraction for the production of the reformed crude oil (a naphtha fraction utilization step). <P>COPYRIGHT: (C)2009,JPO&INPIT

Description

  The present invention relates to a method for producing reformed crude oil, and more particularly, to a method for producing reformed crude oil in which efficiency is achieved by including a specific step.

  In the refining treatment of crude oil, generally, after crude oil is distilled under atmospheric pressure and separated into fractions, a purification treatment such as desulfurization is performed on each separated fraction. However, this method has a large number of essential oil facilities and a complicated process, and has problems such as poor energy efficiency due to repeated cooling and heating of the product, which is not always satisfactory and more efficient. There is a need for a method for refining crude oil. For these reasons, batch processing of crude oil excluding crude oil or naphtha fraction has been attempted in recent years. For example, Patent Document 1 discloses a method in which a naphtha fraction in crude oil is distilled and separated, and then the residual oil from which the naphtha fraction has been removed is collectively hydrodesulfurized and then distilled to separate each product. Document 2 discloses a crude oil treatment method in which crude oil is hydrodemetallized, hydrocracked, hydrodesulfurized and then gas-liquid separated gas-phase fluid is hydroreformed.

  By the way, crude oil has different types and proportions of hydrocarbons depending on the production area, etc., but in recent years it is caused by the tendency of the crude oil produced to become heavier and the price difference between heavy crude oil and light crude oil. Therefore, it is required to improve the quality of inferior crude oil containing a large amount of heavy components and to use it effectively. However, at present, there is a problem in terms of efficiency to improve the quality of such inferior crude oil, and further technological development is necessary.

JP-A-3-294390 JP 2000-136391 A

  The present invention has been made in such a situation, and an object of the present invention is to provide a method for producing a reformed crude oil which can efficiently improve the quality even in poor quality crude oil.

Crude oil is divided into fractions by distillation, and then various petroleum products are produced by refining treatment and the like. Since the consumption by this fraction is affected by the industry and social environment in each region, the fraction with high demand varies from region to region. For example, naphtha distillate is in high demand as a raw material in the gasoline and petrochemical industries, but these applications are not always available in all regions, and new application development is also necessary.
As a result of diligent research, the present inventors have found that the quality can be efficiently improved even in the above-mentioned poor crude oil by including the specific process and utilizing the characteristics of the naphtha fraction. It came to do. That is, the present invention
(1) Separating a naphtha fraction from crude oil to obtain a truncated crude oil (naphtha fraction separation process), hydrotreating the truncated crude oil (trapped crude oil hydrotreating process), and modifying the naphtha fraction into a modified crude oil A method for producing reformed crude oil, including a step (naphtha fraction use step) used for the production of naphtha, wherein the naphtha fraction use step is part or all of the naphtha fraction obtained in the naphtha fraction separation step A method for producing a modified crude oil characterized in that
(2) A process for separating a naphtha fraction from crude oil to obtain a truncated crude oil (naphtha fraction separation process), a process for hydrotreating the truncated crude oil (headed crude oil hydrotreating process), and a modified crude oil from the naphtha fraction A method for producing reformed crude oil, including a step (naphtha fraction use step) used for the production of naphtha, wherein the naphtha fraction use step is part or all of the naphtha fraction obtained in the naphtha fraction separation step A process for producing reformed crude oil, characterized in that hydrogen is produced from the raw material and the hydrogen is used in a crude oil hydrotreating process,
(3) After the naphtha fraction use step performs hydrodesulfurization treatment on the naphtha fraction obtained in the naphtha fraction separation step, hydrogen is produced using the treated naphtha fraction as a raw material, and the hydrogen (2), wherein a part of the crude oil is used in a crude oil hydrotreating process, and at least a part of the remaining hydrogen is used for hydrodesulfurization treatment of the naphtha fraction. A method for producing modified crude oil,
(4) Separating naphtha fraction from crude oil to obtain truncated crude oil (naphtha fraction separation process), hydrotreating the truncated crude oil (trapped crude oil hydrotreating process), and reforming crude oil into the naphtha fraction A method for producing reformed crude oil, including a process (naphtha fraction utilization process) used for the production of naphtha, wherein the naphtha fraction utilization process sweetens the naphtha fraction obtained in the naphtha fraction separation process. A method for producing a reformed crude oil, characterized in that at least a part of the sweetening naphtha obtained by mixing with the refined extracted crude oil that has undergone a pre-cracked crude oil hydrotreating process,
(5) A process for separating a naphtha fraction from crude oil to obtain a truncated crude oil (naphtha fraction separation process), a process for hydrotreating the truncated crude oil (headed crude oil hydrotreating process), and reforming the naphtha fraction into a modified crude oil A method for producing reformed crude oil, including a process (naphtha distillate utilization process) used for the production of naphtha, in which the naphtha distillate utilization process hydrotreats the naphtha distillate obtained in the naphtha distillate separation process. Then, at least a part of the gasoline base material obtained by the catalytic reforming process is mixed with the reformed and extracted crude oil that has undergone the extracted crude oil hydrogenation process, And (6) the extracted crude oil hydrotreating step includes at least one of a hydrodemetallation step, a hydrocracking step, and a hydrodesulfurization step, according to any one of (1) to (5) above, A method for producing reformed crude oil is provided.
In this specification, improving quality is sometimes referred to as “reforming”, and a crude oil whose quality has been improved by hydroprocessing or the like is referred to as a “reformed natural oil”, and a crude oil whose quality has been improved. It is called “reformed crude oil”.

  ADVANTAGE OF THE INVENTION According to this invention, the manufacturing method of reformed crude oil which can improve quality efficiently also in poor quality crude oil is provided. The method for producing the modified crude oil includes a step of separating a naphtha fraction from crude oil to obtain a truncated crude oil (a naphtha fraction separation step), a step of hydrotreating the truncated crude oil (a truncated crude oil hydrotreating step), and the naphtha. Including a step of using the fraction for production of reformed crude oil (a naphtha fraction use step). As a result, efficiency in the production of the reformed crude oil can be improved, and the naphtha fraction can be used for a new application, so that the supply and demand balance of petroleum products can be easily adjusted.

The method for producing a modified crude oil of the present invention includes a step of separating a naphtha fraction from crude oil to obtain a truncated crude oil (a naphtha fraction separation step), a step of hydrotreating the truncated crude oil (a truncated crude oil hydrotreating step), and Including a step of using the naphtha fraction for the production of reformed crude oil (a naphtha fraction utilization step).
When hydrotreating crude oil, generally, if there is a fraction lighter than a naphtha fraction, the vapor partial pressure of the gas phase tends to decrease due to the vaporization of these fractions, making it difficult to achieve efficient hydrotreatment. In addition, when the modified crude oil is produced without separating the naphtha fraction from the crude oil, the sulfur content in the naphtha, kerosene, and light oil fractions obtained by distilling the modified crude oil tends to increase. Therefore, in the present invention, the naphtha fraction is separated from the crude oil to obtain a truncated crude oil (residue obtained by separating the naphtha fraction from the crude oil), and then hydrogenation treatment is performed on the truncated crude oil. Furthermore, by using the naphtha fraction obtained in the naphtha fraction separation step for the production of the reformed crude oil, the reformed crude oil can be produced more efficiently. Process diagrams of the present invention are shown in FIGS.
Below, the manufacturing method of the reformed crude oil of this invention is demonstrated for every process.

[Naphtha fraction separation process]
The naphtha fraction separation step is a step of separating a naphtha fraction from crude oil to obtain a truncated crude oil.
The crude oil used in the present invention is not limited to oil well-derived untreated oil (petroleum-based crude oil), but also coal liquefied oil, tar sand oil, oil sand oil, oil shale oil, orinocotal, etc., or a synthesis obtained therefrom. It may be crude oil. Moreover, you may use the mixed oil which consists of said crude oil 2 types or more.

The crude oil of the present invention preferably has a content of asphaltene (in the present specification, asphaltene means an n-heptane insoluble matter when extracted from crude oil with n-heptane). It is above, and 2 mass% or more is more preferable. Although there is no problem with the properties of the modified crude oil obtained even if crude oil of less than 1% by mass is used, it is not preferable from the viewpoint of cost effectiveness and energy saving. Moreover, although there is no restriction | limiting in particular about an upper limit, Less than 15 mass% is preferable on an apparatus operation. For the same reason, crude oil containing 10 mass ppm or more of vanadium and nickel and 0.1 mass% or more of sulfur is preferably used.
The crude oil is preferably pretreated if necessary. For example, when the salt concentration is high, it is preferable to perform a desalting treatment so that sodium chloride is 10 mass ppm or less. Moreover, when there is much solid content, it is preferable to pass a filter about 10 micrometers.

Examples of the method for separating the naphtha fraction from the crude oil include a method using a general preflash drum or a preflash column. It is preferable that the operating temperature is 150 to 300 ° C. and the pressure is ^{2 to} 10 kg / cm ² G.
The boiling point of the naphtha fraction is determined by crude oil at the initial boiling point, and the end point is preferably in the range of 125 to 174 ° C. When the end point is lower than 125 ° C., the hydrogen partial pressure is lowered in the subsequent staged crude oil hydrotreating process, and thus the reaction rate is likely to be lowered. Moreover, if the end point exceeds 174 ° C., the sulfur content of the kerosene fraction in the reformed crude oil may increase and become out of product specifications.

[Headed crude oil hydrogenation process]
The extracted crude oil hydrotreating process is a process of improving the quality by hydrotreating the extracted crude oil.
Examples of the hydrogenation treatment include hydrodemetallation treatment, hydrocracking treatment, hydrodesulfurization treatment, hydrodenitrogenation treatment, hydrodearomatization treatment, and the like.

  The hydrodemetallation treatment is carried out in a single-column to multiple-column reaction tower after the heated crude oil is pressurized and heated. Catalysts used for the hydrodemetallation treatment include porous inorganic oxides such as alumina, silica, silica-alumina or sepiolite, oxidation carriers, natural minerals, etc., periodic tables 5, 6, 8, 9 and 10 A catalyst having an average pore diameter of 100 μm or more formed by supporting about 3 to 30% by mass of an oxide based on at least one selected from metals belonging to the group based on the total amount of the catalyst. Other hydrodemetallation catalysts such as commercially available hydrodemetallation catalysts for heavy oil direct desulfurization equipment may also be used. The required amount of the hydrodemetallation catalyst is preferably 10 to 80% by volume of the cumulative amount of metal contained in the extracted crude oil during the treatment period.

The treatment conditions for the hydrodemetallation treatment are as follows: reaction temperature 300 to 450 ° C., hydrogen partial pressure 30 to 200 kg / cm ² G, hydrogen / oil ratio 200 to 2000 Nm ³ / kl, LHSV (liquid hourly space velocity) 0.1 ~10h ^-1, further reaction temperature three hundred fifty to four hundred and ten ° C., a hydrogen partial pressure 100~180kg / cm ² G, hydrogen / oil ratio 400~800Nm ³ /kl,LHSV0.3~5h ^-1 desirable. This is because if the reaction temperature, hydrogen partial pressure, and hydrogen / oil ratio are less than the desired ranges, the reaction efficiency decreases, and if they exceed the ranges, the economic efficiency decreases. On the other hand, if LHSV exceeds the desired range, the reaction efficiency decreases, and if it falls below the range, the economic efficiency decreases.

  The hydrocracking treatment is usually performed after a hydrogenation treatment such as a hydrodemetallation treatment. Therefore, when it is necessary to control the reaction temperature, it is preferable to control the reaction temperature by a heat exchanger, hydrogen gas quenching or oil quenching. The hydrocracking treatment is performed in a single tower to a plurality of towers. The catalyst used for the hydrocracking treatment is not particularly limited, but 10 to 90% by mass of an iron-containing aluminosilicate and an inorganic oxide produced by the technique disclosed in Japanese Patent Laid-Open No. 2-289419. It is also possible to use a carrier comprising 90 to 10% by mass with at least one selected from metals belonging to Groups 6, 8, 9 and 10 of the periodic table. Using an iron-containing aluminosilicate obtained by treating this steamed steaming zeolite with an iron salt aqueous solution is very effective in increasing the decomposition rate from a fraction of 343 ° C or higher to a fraction of 343 ° C or lower. is there. Further, those produced by the techniques disclosed in JP-A-60-49131, JP-A-61-24433, JP-A-3-21484 and the like can be used. That is, at least one selected from metals belonging to Groups 6, 8, 9 and 10 of the periodic table was supported on a support composed of 20 to 80% by mass of an iron-containing aluminosilicate and 80 to 20% by mass of an inorganic oxide. As the metal belonging to Group 6 of the periodic table, tungsten and molybdenum are preferable, and metals of Groups 7 to 10 of the periodic table may be used singly, or a plurality of metals may be combined. Although it is good, the combination of Ni—Mo, Co—Mo, Ni—W, and Ni—Co—Mo is particularly preferable because of its high hydrogenation activity and little deterioration.

The hydrocracking treatment conditions include a reaction temperature of 370 to 450 ° C., a hydrogen partial pressure of 30 to 200 kg / cm ² G, a hydrogen / oil ratio of 200 to 2000 Nm ³ / kl, an LHSV (liquid hourly space velocity) of 0.1 10 h ⁻¹ , a reaction temperature of 380 to 410 ° C., a hydrogen partial pressure of 100 to 180 kg / cm ² G, a hydrogen / oil ratio of 400 to 800 Nm ³ / kl, and an LHSV of 0.3 to ⁵ h ⁻¹ are desirable. This is because if the reaction temperature, hydrogen partial pressure, and hydrogen / oil ratio are less than the desired ranges, the reaction efficiency decreases, and if they exceed the ranges, the economic efficiency decreases. On the other hand, if LHSV exceeds the desired range, the reaction efficiency decreases, and if it falls below the range, the economic efficiency decreases.

  The hydrodesulfurization treatment is usually performed after a hydrogenation treatment such as a hydrodemetallation treatment. Therefore, when it is necessary to control the reaction temperature, it is preferable to control the reaction temperature by a heat exchanger, hydrogen gas quenching or oil quenching. The hydrodesulfurization treatment is performed in a single tower to a plurality of towers. The catalyst used in the hydrodesulfurization treatment may be a hydrodesulfurization catalyst for a normal heavy oil direct desulfurization apparatus. That is, at least one selected from the metals belonging to Groups 5, 6, 8, 9 and 10 of the periodic table is used as an oxide based on the total amount of the catalyst. What carried about 3-30 mass% may be sufficient. A catalyst having an average pore diameter of 80 mm or more, such as an alumina-phosphorus carrier, an alumina-alkaline earth metal carrier compound, and alumina-titania as disclosed in JP-A-7-305077 and JP-A-5-98270. A catalyst comprising at least one selected from metals belonging to Groups 5, 6, 8, 9 and 10 of the periodic table on a support selected from a support, an alumina-zirconia support, an alumina-boria support, and the like. For example, it is suitable because the reforming effect of the kerosene oil fraction is high.

The treatment conditions in the hydrodesulfurization treatment are as follows: reaction temperature 300 to 450 ° C., hydrogen partial pressure 30 to 200 kg / cm ² G, hydrogen / oil ratio 200 to 2000 Nm ³ / kl, LHSV (liquid hourly space velocity) 0.1 10 h ⁻¹ , a reaction temperature of 320 to 420 ° C., a hydrogen partial pressure of 100 to 180 kg / cm ² G, a hydrogen / oil ratio of 400 to 800 Nm ³ / kl, and an LHSV of 0.2 to ² h ⁻¹ are desirable. This is because if the reaction temperature, hydrogen partial pressure, and hydrogen / oil ratio are less than the desired ranges, the reaction efficiency decreases, and if they exceed the ranges, the economic efficiency decreases. On the other hand, if LHSV exceeds the desired range, the reaction efficiency decreases, and if it falls below the range, the economic efficiency decreases.

  The hydrodearomatic treatment is preferably performed on the gas phase fluid obtained by the gas-liquid separation treatment, and the kerosene fraction or light oil fraction obtained by distilling the crude oil extracted by hydrodearomatic treatment. Aromatic content can be reduced.

  The gas-liquid separation treatment is performed after controlling the temperature of the extracted crude oil after the hydrogenation treatment such as hydrodemetallation treatment to a desired separation temperature using a heat exchanger. Normally, the gas-liquid separation process may be performed using a high-pressure and high-temperature gas-liquid separation tank with the same structure as the heavy oil direct desulfurization unit. However, in order to maintain the reaction efficiency in the subsequent hydrodearomatic process, the high-pressure and high-temperature gas-liquid separation tank Measures to prevent heavy oil from being mixed into the gas phase fluid separated in the tank, such as taking a sufficiently large tower diameter of the gas-liquid separation tank, or arranging a sufficient amount of mist separator inside the gas-liquid separation tank, etc. It is better to take The high-pressure and high-temperature gas-liquid separation tank is composed of one tower to a plurality of towers.

The gas-liquid separation treatment is desirably performed in a pressure range lower by 0 to 50 kg / cm ² and in a temperature range lower by 0 to 100 ° C. than the previous hydrogenation treatment. As a separation condition in the gas-liquid separation process, if the separation pressure is reduced below 50 kg / cm ² G with respect to the pressure at the hydrotreating process outlet, the reaction efficiency in the subsequent hydrodearomatic treatment is lowered due to the decrease in the hydrogen partial pressure. In addition, heavy oil is likely to be mixed into the gas phase fluid subjected to the subsequent hydrodearomatic treatment. As a reference in this case, it is preferable to maintain the proportion of the fraction of 400 ° C. or higher mixed in the gas phase fluid at 3% by mass or less with respect to the total amount of the gas phase fluid. Further, in order to make the separation pressure equal to or higher than the pressure at the outlet of the hydrotreating process, equipment for increasing the pressure, for example, a compressor is required, so that the construction cost of the apparatus increases. When the separation temperature is lowered by more than 100 ° C with respect to the temperature of the hydrotreating process outlet, the proportion of kerosene oil fraction separated as a gas phase fluid is small in the kerosene fraction in the fluid before gas-liquid separation. Therefore, the kerosene fraction used for the subsequent hydrodearomatic treatment is reduced, and the hydrodearomatic treatment of the kerosene fraction cannot be performed efficiently. Also, in order to make the separation temperature higher than the temperature at the hydrotreating process outlet, heating equipment such as a heating furnace is required, so that the construction cost of the apparatus increases.

  The hydrodearomatic treatment is performed in one to a plurality of reaction towers, and is usually performed without heating or raising the temperature of the gas phase fluid from the gas-liquid separation treatment. When it is necessary to control the reaction temperature of the gas phase fluid, the fluid temperature is changed by a heat exchanger or the like. If the reaction temperature can be controlled with hydrogen gas or recycled oil, the hydrodearomatic treatment is performed as it is. A normal fixed bed may be used as a reaction tower type in the hydrodearomatic treatment. The catalyst used in the hydrodearomatic treatment may be a normal middle distillate hydrogenation catalyst. That is, as an oxide based on the total amount of the catalyst, at least one selected from metals belonging to Groups 5, 6, 8, 9 and 10 of the periodic table is used as a support of alumina, silica, zeolite or a mixture thereof. A catalyst having an average pore diameter of 80 mm or more supported on the order of 3 to 30% by mass, such as an alumina-phosphorus carrier and an alumina as disclosed in JP-A-7-305077 and JP-A-5-98270. The support selected from alkaline earth metal support compounds, alumina-titania support, alumina-zirconia support, alumina-boria support, etc., was selected from the metals belonging to Groups 5, 6, 8, 9 and 10 of the periodic table A catalyst supporting at least one kind is preferable because the hydrodearomatic treatment effect of the kerosene oil fraction is high.

The treatment conditions in the hydrodearomatic treatment are usually the same as the separation temperature and the separation pressure in the gas-liquid separation step because the reaction is performed without heating or heating equipment following the gas-liquid separation step. is there. That is, a reaction temperature of 300 to 400 ° C. and a reaction pressure of 100 to 180 kg / cm ² G are desirable. In order to effectively use the temperature and pressure at the hydrotreatment process outlet in the previous stage for hydrodearomatic treatment, the reaction temperature is -100 to 0 ° C with respect to the temperature at the hydrotreatment process exit, and the reaction pressure is hydrogenation A range of −50 to 0 kg / cm ² is suitable for the pressure at the treatment process outlet. The hydrogen partial pressure is preferably 70 to 150 kg / cm ² G, the hydrogen / oil ratio is 500 to 2000 Nm ³ / kl, and the LHSV (liquid hourly space velocity) is preferably 0.5 to 10 h ⁻¹ . This is because if the reaction temperature, hydrogen partial pressure, and hydrogen / oil ratio are less than the desired ranges, the reaction efficiency decreases, and if they exceed the ranges, the economic efficiency decreases. On the other hand, if LHSV exceeds the desired range, the reaction efficiency decreases, and if it falls below the range, the economic efficiency decreases.

  The fluid subjected to the hydrodearomatic treatment is mixed with the liquid phase fluid obtained in the gas-liquid separation step to obtain a modified and extracted crude oil. As will be described later, the modified crude oil of the present invention is the modified truncated crude oil or a mixture of sweetened naphtha or gasoline base material with the modified truncated crude oil. Depending on the region, it may be necessary to produce the above-described modified crude oil rather than producing a petroleum product, and the method for producing the modified crude oil of the present invention is preferably applied. For example, it is located near the crude oil shipping facility in the oil-producing country and the crude oil shipping facility is in place, but this is the case when the facility is installed in a place where there is no petroleum product shipping facility. In such a case, it is obtained by introducing reformed crude oil or reformed crude oil from which hydrogen sulfide has been removed (the reformed crude oil is introduced into equipment for removing hydrogen sulfide associated with the desulfurization apparatus, such as a hydrogen sulfide stripper). ), The existing crude oil shipping equipment can be used as it is, and a large crude oil tanker can be used for transportation in large quantities and at low cost.

[Naphtha fraction use process]
The naphtha fraction utilization process is a process for efficiently producing the reformed crude oil by using the naphtha fraction for the production of the reformed crude oil.
The naphtha fraction use process of the present invention has the following three aspects. That is,
(Aspect 1) A naphtha fraction is used as a quench oil in a precipitating crude oil hydrotreating process.
(Aspect 2) Hydrogen is produced from a naphtha fraction, and the hydrogen is used for hydrotreating such as a crude oil hydrotreating step.
(Aspect 3) The naphtha fraction is subjected to a refining treatment, and the naphtha fraction after the treatment is mixed with the modified truncated crude oil after the extracted crude oil hydrotreating process.
Hereinafter, each aspect will be described in detail.

The naphtha fraction utilization process of aspect 1 is demonstrated based on FIG.
The crude oil 11 is separated into the naphtha fraction 12 and the withdrawn crude oil 13 in the naphtha fraction separating process 1, and the modified crude oil 15 is produced from the withdrawn crude oil 13 through the withdrawn crude oil hydrotreating process 2. The naphtha fraction separation process 1 and the extracted crude oil hydrogenation process 2 are as described above.
Part or all of the naphtha fraction 12 is used as a quench oil in the extracted crude oil hydrotreating step 2. When the naphtha fraction is introduced into a reaction tower for hydrotreating, most of the naphtha fraction evaporates and takes away the latent heat of vaporization, so that it functions as a good quenching agent and the process efficiency is improved.

  The amount of the naphtha fraction used as the quenching agent can be appropriately determined according to the purpose. Therefore, the remaining naphtha fraction used as the quenching agent may be mixed with the reformed crude oil, or may be used as a raw material for gasoline production or a raw material for the petrochemical industry.

The naphtha fraction utilization process of aspect 2 is demonstrated based on FIG.
The crude oil 11 is separated into the naphtha fraction 12 and the withdrawn crude oil 13 in the naphtha fraction separating process 1, and the modified crude oil 15 is produced from the withdrawn crude oil 13 through the withdrawn crude oil hydrotreating process 2. The naphtha fraction separation process 1 and the extracted crude oil hydrogenation process 2 are as described above.
A part or all of the naphtha fraction 12 is subjected to a hydrogen production process 5 to produce hydrogen 14. At this time, depending on the purpose, the hydrodesulfurization step 4 may be performed before the hydrogen production step 5. The produced hydrogen 14 is used in the hydrodesulfurization process 4 and the extracted crude oil hydrotreating process 2. A part of hydrogen may be taken out and used for other purposes.

In the hydrogen production step 5, the naphtha fraction is supplied together with steam to a hydrogen production apparatus using a steam reforming method. Moreover, it is preferable to make a sulfur content into 0.5 ppm or less by the said hydrodesulfurization process 4. FIG. It is preferable to perform the desulfurization treatment under relatively mild conditions, and a reaction pressure of 7 to 30 kg / cmG, a hydrogen oil ratio of 30 to 80 Nm ³ / kl, and LHSV of 6 to 10 hours are preferable.

  In the refining process of crude oil, a hydrogenation reaction is often used, and natural gas and oil field associated gas are often used as a hydrogen raw material. However, in some cases, these hydrogen raw materials cannot be used. In such a case, it is possible to efficiently produce reformed crude oil by using the naphtha fraction obtained in the naphtha fraction separation step as a hydrogen raw material. it can.

The naphtha fraction utilization process of aspect 3 is demonstrated based on FIG. 3 (aspect 3a) and FIG. 4 (aspect 3b).
The crude oil 11 is separated into the naphtha fraction 12 and the withdrawn crude oil 13 in the naphtha fraction separating process 1, and the modified crude oil 15 is produced from the withdrawn crude oil 13 through the withdrawn crude oil hydrotreating process 2. The naphtha fraction separation process 1 and the extracted crude oil hydrogenation process 2 are as described above.

In FIG. 3, a part or all of the naphtha fraction 12 is subjected to a sweetening process 6 to produce a sweetening naphtha 17. A part or all of the sweetening naphtha 17 is mixed in the modified crude oil 15 to produce the modified crude oil 16.
When the naphtha fraction 12 separated in the naphtha fraction separation step 1 is mixed with reformed crude oil to produce reformed crude oil, hydrogen sulfide and mercaptans contained in the naphtha fraction 12 may cause safety problems or corrosion. Therefore, the content of hydrogen sulfide or mercaptan is reduced by the sweetening process 6. As specific methods, there are a method called Merox method and Mericat method, a method of contacting a liquid consisting of an aqueous caustic soda solution and a catalyst with a naphtha fraction under mild conditions, and a method of adsorbing hydrogen sulfide or mercaptan to activated clay at room temperature. Can be selected as appropriate in consideration of cost and efficiency. In the sweetening step 6, the content of hydrogen sulfide or mercaptan in the sweetening naphtha 17 is preferably 10 ppm or less, and more preferably 5 ppm or less.

  As described above, the sweetened naphtha 17 is mixed with the reformed crude oil 15 to produce the reformed crude oil 16. By simply distilling the reformed crude oil, a gasoline base having a high octane number and a high added value are obtained. A light oil fraction can be obtained efficiently.

In FIG. 4, the gasoline base material 18 is manufactured through a hydrodesulfurization process 4 and a catalytic reforming process 7 for a part or all of the naphtha fraction 12. Part or all of the gasoline base material 18 is mixed into the modified extracted crude oil 15 to produce the modified crude oil 16.
In the hydrodesulfurization step 4, the sulfur content in the naphtha fraction 12 is preferably 0.5 ppm or less. It is preferable to perform the desulfurization treatment under relatively mild conditions, and a reaction pressure of 7 to 30 kg / cmG, a hydrogen oil ratio of 30 to 80 Nm ³ / kl, and LHSV of 6 to 10 hours are preferable.
The naphtha fraction 12 is catalytically reformed by the catalytic reforming process 7 subsequent to the hydrodesulfurization process 4 to improve the octane number. The catalytic reforming step is preferably supplied to a low-pressure, multistage reaction tower at a high temperature.

  As described above, by mixing the gasoline base 18 with the modified crude oil 15 to produce the reformed crude 16, a gasoline base having a high octane number can be obtained simply by distilling the reformed crude. . Furthermore, the hydrogen 14 produced as a by-product in the catalytic reforming process 7 is used in the hydrodesulfurization process 4 and the extracted crude oil hydrogenation reforming process 2. A part of hydrogen may be taken out and used for other purposes.

  ADVANTAGE OF THE INVENTION According to this invention, the manufacturing method of reformed crude oil which can improve quality efficiently also in poor quality crude oil is provided. The method for producing reformed crude oil includes a naphtha fraction separation process, a crude oil hydrotreating process, and a naphtha fraction utilization process, which improves efficiency in the production of reformed crude oil and introduces a new naphtha fraction. It can be used in various applications, and it becomes easy to adjust the supply and demand balance of petroleum products.

It is process schematic of an example (embodiment 1) of the manufacturing method of the modified crude oil of this invention. It is process schematic of an example (embodiment 2) of the manufacturing method of the modified crude oil of this invention. It is process schematic of an example (aspect 3a) of the manufacturing method of the reformed crude oil of this invention. It is process schematic of an example (aspect 3b) of the manufacturing method of the modified crude oil of this invention.

Explanation of symbols

1: naphtha fraction separation process 2: extracted crude oil hydrogenation process 3: quench process 4: hydrodesulfurization process 5: hydrogen production process 6: sweetening process 7: catalytic reforming process 11: crude oil 12: naphtha fraction 13 : Extracted crude oil 14: Hydrogen 15: Reformed extracted crude oil 16: Reformed crude oil 17: Sweetening naphtha 18: Gasoline base material

Claims (6)

Separating naphtha fraction from crude oil to obtain truncated crude oil (naphtha fraction separation process), hydrotreating the truncated crude oil (trapped crude oil hydrotreating process), and producing the modified crude oil from the naphtha fraction A method for producing reformed crude oil, including a process to use (naphtha fraction use process),
A modified crude oil characterized in that the naphtha fraction utilization step uses part or all of the naphtha fraction obtained in the naphtha fraction separation step as a quench oil in the extracted crude oil hydrotreating step. Manufacturing method. Separating naphtha fraction from crude oil to obtain truncated crude oil (naphtha fraction separation process), hydrotreating the truncated crude oil (trapped crude oil hydrotreating process), and producing the modified crude oil from the naphtha fraction A method for producing reformed crude oil, including a process to use (naphtha fraction use process),
The naphtha fraction utilization process is to produce hydrogen using a part or all of the naphtha fraction obtained in the naphtha fraction separation process as a raw material, and to use the hydrogen in the crude oil hydrotreating process. A method for producing reformed crude oil.   After the naphtha fraction utilization step performs hydrodesulfurization treatment on the naphtha fraction obtained in the naphtha fraction separation step, hydrogen is produced using the naphtha fraction after the treatment as a raw material, and a part of the hydrogen The modified crude oil according to claim 2, wherein at least part of the remaining hydrogen is used for hydrodesulfurization treatment of the naphtha fraction. Production method. Separating naphtha fraction from crude oil to obtain truncated crude oil (naphtha fraction separation process), hydrotreating the truncated crude oil (trapped crude oil hydrotreating process), and producing the modified crude oil from the naphtha fraction A method for producing reformed crude oil, including a process to use (naphtha fraction use process),
The naphtha fraction use process mixes at least part of the sweetened naphtha obtained by sweetening the naphtha fraction obtained in the naphtha fraction separation process with the modified extracted crude oil that has undergone the extracted crude oil hydrotreating process. A method for producing reformed crude oil, characterized in that: Separating naphtha fraction from crude oil to obtain truncated crude oil (naphtha fraction separation process), hydrotreating the truncated crude oil (trapped crude oil hydrotreating process), and producing the modified crude oil from the naphtha fraction A method for producing reformed crude oil, including a process to use (naphtha fraction use process),
The naphtha fraction use process is a crude oil hydrotreating process for at least part of the gasoline base material obtained by hydrodesulfurizing the naphtha fraction obtained in the naphtha fraction separation process and then catalytic reforming. A method for producing a reformed crude oil characterized by being mixed with a modified extracted crude oil that has undergone the process.   The method for producing a reformed crude oil according to any one of claims 1 to 5, wherein the extracted crude oil hydrotreating process includes at least one of a hydrodemetallation process, a hydrocracking process, and a hydrodesulfurization process.

Images