A method and system for hydrogenating heavy crude oil in a liquid phase non-hydrogen slurry bed

Abstract

The present disclosure relates to a method and system for hydrogenating heavy crude oil in a liquid non-hydrogenated slurry bed, the method comprising: mixing crude oil, catalyst and hydrogen supply agent and entering into a slurry bed reactor for hydrogen transfer reaction to obtain hydrogen transfer reaction products; the hydrogen transfer reaction products are subjected to a first separation to obtain gas phase light components, mixed light oil, heavy oil products and unconverted oil containing catalyst; a portion of the unconverted oil is returned to the slurry bed reactor for further reaction; the mixed light oil is subjected to a second separation to obtain product light oil and a hydrogen supply agent to be produced. The method disclosed in the present disclosure can reduce coking and reduce the pressure of the reaction system, thereby improving the safety, reliability and long-term operation of the device.

Description

Technical Field

[0001] The present disclosure relates to the field of petrochemical industry, and in particular, to a method and system for hydrogenating heavy crude oil in a liquid-phase non-hydrogen-containing slurry bed. Background Art

[0002] Today, as the whole society is increasingly calling for sustainable development and green environmental protection, oil refining companies are facing the competitive pressure of rising crude oil prices, deteriorating crude oil properties, rising demand for light oil products, and stricter fuel and environmental protection standards. At present, there are four major types of residue oil hydrogenation processes in the world, namely fixed bed, ebullating bed, moving bed and slurry bed residue oil hydrogenation. The advantage of slurry bed hydrogenation technology is that it can process the poorest residue oil, even coal, but its reaction system pressure is high, the chemical hydrogen consumption is higher than that of fixed bed, ebullating bed and moving bed, and the equipment investment is high. Under the background of carbon peak and carbon neutrality, reducing the pressure of the reaction system is of vital importance to energy saving and consumption reduction of the entire device and achieving carbon peak and carbon neutrality.

[0003] In the slurry bed residue oil hydrogenation, the reaction system is under high pressure and in the presence of hydrogen. The raw oil has poor properties and severe coking. In addition, due to the low molecular weight of hydrogen, it is easy to escape and leak, causing great safety risks. At the same time, the device operates under high pressure conditions, with high equipment investment and high safety risks, which brings great troubles to the stable, safe and long-term operation of the slurry bed residue oil hydrogenation device using the existing technology.

[0004] CN1388219A discloses a catalytic conversion method for reducing the olefin content of gasoline by using a hydrogen supply component. The method is characterized in that a catalytic cracking process is applied to saturate light raw materials, thereby improving product properties. However, when the catalytic cracking reactor is used to process inferior heavy oil, especially high-viscosity heavy oil, the catalyst cokes severely, which seriously affects the long-term operation of the device.

[0005] CN1393524A and CN105567319A disclose a method for lightening heavy and residual oils and a method for treating heavy oils, respectively. The characteristics of the methods are that distillate oil is used as a hydrogen donor, and under the action of hydrogen, it is mixed with raw materials and catalysts and then subjected to high-pressure hydrogenation treatment or hydrocracking, and the hydrogen donor is subjected to fixed-bed hydrogenation and circulation, so that heavy residual oil can be treated. However, hydrogen and the hydrogen donor participate in the reaction at the same time, the reaction pressure of the hydrogen reaction is high, and the hydrogen donor is used as an additive or auxiliary agent, which is not conducive to energy saving and consumption reduction of the device, and the device operation is difficult.

[0006] CN102504862A and CN105505449A disclose a hydrogen supply thermal cracking method and a hydrogen supply coking method, respectively. Distillate oil is used as a hydrogen supply agent and mixed with a heavy raw material and then heated to a higher temperature to thermally crack the raw material, thereby reducing the viscosity of the raw material and the coke yield. However, this method does not require the addition of a catalyst, and the loss of the hydrogen supply agent during the thermal cracking process is large, and the efficiency is low.

[0007] In the prior art, hydrogen thermal cracking is widely used in the viscosity reduction of crude oil. Common hydrogen donors include its own distillate oil, alcohols, formic acid and its salts, cyclohexene, hydrazine hydrate, triethylsilane, water, etc. The methods used include hydrogen thermal cracking, microwave thermal cracking, hydrocracking, hydrorefining, etc. Among them, hydrocracking or hydrorefining requires the introduction of external hydrogen and operates under hydrogen conditions. The catalyst used is often a solid catalyst and a fixed bed reactor. The hydrogen donor uses its own distillate oil or a one-time injection of chemicals. The large amount of chemicals and hydrogen consumed in circulation leads to increased investment. Some by-products of the hydrogen donor may be difficult to separate from the product, resulting in unqualified product indicators. Summary of the invention

[0008] The purpose of the present disclosure is to solve the problems of severe coking, unstable product distribution, low equipment safety and high energy consumption of the device when processing high-viscosity heavy crude oil.

[0009] In order to achieve the above-mentioned purpose, the first aspect of the present disclosure provides a method for hydrogenating heavy crude oil in a liquid phase non-hydrogenated slurry bed, the method comprising: mixing the crude oil, a catalyst and a hydrogen donor and then entering into a slurry bed reactor for hydrogen transfer reaction to obtain a hydrogen transfer reaction product; subjecting the hydrogen transfer reaction product to a first separation to obtain a gas phase light component, a mixed light oil, a heavy oil product and an unconverted oil containing the catalyst; returning a portion of the unconverted oil to the slurry bed reactor for further reaction; subjecting the mixed light oil to a second separation to obtain a product light oil and a hydrogen donor to be produced.

[0010] Optionally, the feedstock oil is selected from one or more of vacuum residue, deasphalted oil, atmospheric residue, crude oil fractions with an initial boiling point greater than 350°C and extra-thick crude oil; the hydrogen donor is selected from one or more of cyclohexane, cyclohexene, cyclohexadiene, methylcyclohexane and decalin, preferably cyclohexane; the catalyst is selected from one or more of oil-soluble catalysts, supported nickel-molybdenum powder catalysts, non-precious metal catalysts and precious metal solid catalysts, preferably oil-soluble organic homogeneous molybdenum catalysts; the non-precious metal in the non-precious metal catalyst includes one or more of nickel, molybdenum and iron, and the precious metal in the precious metal solid catalyst includes one or more of platinum, gold, silver, ruthenium, rhodium and palladium.

[0011] Optionally, the hydrogen transfer reaction conditions include: reaction temperature of 150-450°C, preferably 420-430°C; reaction pressure of 5-70 bar, preferably 35-50 bar; reaction time of 0.5-24 h, preferably 0.5-2.5 h; the usage ratio of the feedstock oil to the hydrogen donor is 1.25-100, preferably 2-5.

[0012] Optionally, the first separation is carried out in one or more of a stripping tower, an atmospheric distillation tower and a vacuum distillation tower; the cut point between the gas phase light component and the mixed light oil is 40-60°C, the cut point between the mixed light oil and the heavy oil product is 300-360°C, and the cut point between the heavy oil product and the unconverted oil is 480-540°C.

[0013] Optionally, the second separation is carried out in a distillation tower, and the cut-off point of the product light oil and the hydrogen donor to be produced is 130-160°C.

[0014] Optionally, the method further comprises: contacting the hydrogen donor to be regenerated with hydrogen to perform a hydrogenation regeneration reaction, and returning the obtained regenerated hydrogen donor to the slurry bed reactor for recycling.

[0015] Optionally, the conditions of the hydrogenation regeneration reaction include: the reaction temperature is 150-250°C, preferably 180-220°C; the reaction pressure is 5-50 bar, preferably 25-35 bar; the volume ratio of the hydrogen to the hydrogen supply agent to be generated is (0.1-999):1.

[0016] Optionally, the method further comprises: sending another portion of the unconverted oil out of the system.

[0017] A second aspect of the present disclosure provides a system for hydrogenating heavy crude oil in a liquid-phase non-hydrogen-containing slurry bed, the system comprising: a slurry bed reactor, a first separation device and a second separation device; the slurry bed reactor comprises a mixed feedstock inlet and a hydrogen transfer product outlet; the first separation device comprises a hydrogen transfer product inlet, a gas phase outlet, a mixed light oil outlet, a heavy oil product outlet and an unconverted oil outlet; the second separation device comprises a mixed light oil inlet, an outlet for a hydrogen supply agent to be produced and a product light oil outlet; the hydrogen transfer product outlet of the slurry bed reactor is connected to the hydrogen transfer product inlet of the first separation device; the unconverted oil outlet of the first separation device is connected to the mixed feedstock inlet of the slurry bed reactor through a circulation pipeline; the mixed light oil outlet of the first separation device is connected to the mixed light oil inlet of the second separation device.

[0018] Optionally, the hydrogen agent regeneration unit includes an inlet for the hydrogen agent to be regenerated, a hydrogen inlet and an outlet for the regenerated hydrogen agent; the outlet for the hydrogen agent to be regenerated of the second separation device is connected to the inlet for the hydrogen agent to be regenerated of the hydrogen agent regeneration unit; the outlet for the regenerated hydrogen agent of the hydrogen agent regeneration unit is connected to the mixed raw material inlet of the slurry bed reactor; the unconverted oil outlet of the first separation device is also led out of the system through a product pipeline.

[0019] Through the above technical scheme, the method described in the present method uses a hydrogen donor to replace hydrogen as a reactant in a slurry bed hydrogenation reaction to carry out a hydrogen transfer reaction, which can reduce coking. This method does not use other distillate oils as hydrogen donors, thereby avoiding affecting the product distribution of the device and avoiding increased energy consumption of the device caused by the circulation of distillate oils. This method maintains the total system pressure of the device at a low level, thereby improving the safety of the method, reducing the device and operating costs, and is conducive to the long-term operation of the device.

[0020] Other features and advantages of the present disclosure will be described in detail in the following detailed description. BRIEF DESCRIPTION OF THE DRAWINGS

[0021] The accompanying drawings are used to provide a further understanding of the present disclosure and constitute a part of the specification. Together with the following specific embodiments, they are used to explain the present disclosure but do not constitute a limitation of the present disclosure. In the accompanying drawings:

[0022] Figure 1 The present invention discloses a process flow chart of an embodiment of a method for hydrogenating heavy crude oil in a liquid-phase non-hydrogen slurry bed.

[0023] Description of Reference Numerals

[0024] A. Slurry bed reactor; B. Separation tower; 2. Distillation tower; 3. Hydrogen donor regeneration unit; 10. Crude oil; 11. Hydrogen donor; 12. Catalyst; 13. Hydrogen transfer reaction product; 14. Gas phase light component; 15. Mixed light oil; 16. Heavy oil product; 17. Circulating unconverted oil; 18. Unconverted oil; 19. Hydrogen; 20. To-be-generated hydrogen donor; 21. Product light oil; 22. Regenerated hydrogen donor. DETAILED DESCRIPTION

[0025] The specific implementation of the present disclosure is described in detail below in conjunction with the accompanying drawings. It should be understood that the specific implementation described herein is only used to illustrate and explain the present disclosure, and is not used to limit the present disclosure.

[0026] In the present disclosure, unless otherwise stated, the terms "first, second" are used for descriptive purposes only and cannot be understood as indicating or implying relative importance or implicitly indicating the number of the indicated technical features. Therefore, the features defined as "first, second" may explicitly or implicitly include one or more of the features. In the description of the present disclosure, the meaning of "plurality" is two or more, unless otherwise clearly and specifically defined.

[0027] The first aspect of the present disclosure provides a method for hydrogenating heavy crude oil in a liquid phase non-hydrogenated slurry bed, the method comprising: mixing the crude oil, a catalyst and a hydrogen donor and introducing the mixture into a slurry bed reactor for hydrogen transfer reaction to obtain a hydrogen transfer reaction product; subjecting the hydrogen transfer reaction product to a first separation to obtain a gas phase light component, a mixed light oil, a heavy oil product and an unconverted oil containing the catalyst; returning a portion of the unconverted oil to the slurry bed reactor for further reaction; subjecting the mixed light oil to a second separation to obtain a product light oil and a hydrogen donor to be produced.

[0028] Through the above technical scheme, the method described in the present invention is adopted, and a hydrogen donor is used instead of hydrogen as a reactant in a slurry bed hydrogenation reaction to carry out a hydrogen transfer reaction, which can reduce coking and reduce the pressure of the reaction system, thereby improving the safety, reliability and long-term operation of the device.

[0029] In one embodiment, the method disclosed in the present disclosure can process many heavy crude oils with high viscosity and many impurities. For example, the crude oil can be selected from one or more of vacuum residue, deasphalted oil, atmospheric residue, crude oil fractions with an initial boiling point of >350°C, and extra-heavy crude oil. In this embodiment, the method can achieve relatively good results when processing the above-mentioned crude oils.

[0030] In one embodiment, the hydrogen donor is selected from one or more of cyclohexane, cyclohexene, cyclohexadiene, methylcyclohexane and decalin, preferably cyclohexane; in the above embodiment, the use of a hydrogen donor instead of hydrogen in the prior art can reduce the pressure during the hydrogen transfer reaction and further enhance the safety of the reaction. At the same time, the hydrogen transfer effect is not much different from the effect of using hydrogen in the traditional process.

[0031] In one embodiment, the catalyst is selected from one or more of an oil-soluble catalyst, a supported nickel-molybdenum powder catalyst, a non-precious metal catalyst and a precious metal solid catalyst, preferably an oil-soluble organic homogeneous molybdenum catalyst; the non-precious metal in the non-precious metal catalyst includes one or more of nickel, molybdenum and iron, and the precious metal in the precious metal solid catalyst includes one or more of platinum, gold, silver, ruthenium, rhodium and palladium. In this embodiment, the catalyst can play a catalytic role, thereby making the reaction more complete, and therefore, the efficiency and completion of the hydrogen transfer reaction can be further improved.

[0032] In one embodiment, the hydrogen transfer reaction conditions include: a reaction temperature of 150 to 450°C, preferably 420 to 430°C; a reaction pressure of 5 to 70 bar, preferably 35 to 50 bar; a reaction time of 0.5 to 24 hours, preferably 0.5 to 2.5 hours; and a mass ratio of the feedstock oil to the hydrogen donor of 1.25 to 100, preferably 2 to 5.

[0033] In the above-mentioned embodiment, in order to improve the reaction effect of the hydrogen transfer reaction, the conditions of the hydrogen transfer reaction and the amount of the reactants are selected; by further optimizing the relevant reaction conditions, the effect of the hydrogen transfer reaction can be further improved.

[0034] Optionally, the method further comprises: after mixing the feedstock oil, the catalyst and the hydrogen donor, the pressure is increased and preheated to 5-70 bar and 150-450° C., the mixture is introduced into a slurry bed reactor for hydrogen transfer reaction, so that the mixed feedstock can quickly reach the reaction temperature when entering the slurry bed reactor, and then react.

[0035] In one embodiment, the first separation is carried out in a separation tower, wherein the separation tower includes one or more of a stripping tower, an atmospheric distillation tower and a vacuum distillation tower; the fraction cut point between the gas phase light component and the mixed light oil is 40-60°C, the fraction cut point between the mixed light oil and the heavy oil product is 300-360°C, and the fraction cut point between the heavy oil product and the unconverted oil is 480-540°C.

[0036] In this embodiment, the hydrogen transfer reaction product is separated into gas phase light components, mixed light oil, heavy oil products and unconverted oil containing catalyst by the first separation. Before the first separation, the hydrogen transfer product and the mixed raw material can be subjected to heat exchange cooling to 270-385° C. before the first separation.

[0037] Furthermore, the separated components are subsequently processed by different processing methods. For example, in one embodiment of the present disclosure, the mixed light oil is subjected to a second separation, wherein the second separation is carried out in a distillation tower, and the fraction cut point of the product light oil and the hydrogen supply agent to be produced is 130-160°C.

[0038] In one embodiment, the method further includes: contacting the hydrogen donor to be regenerated with hydrogen to perform a hydrogenation regeneration reaction, and returning the obtained regenerated hydrogen donor to the slurry bed reactor for recycling; the conditions of the hydrogenation regeneration reaction include: a reaction temperature of 150-250°C, preferably 180-220°C; a reaction pressure of 5-50 bar, preferably 25-35 bar; and a volume ratio of the hydrogen to the hydrogen donor to be regenerated of (0.1-999):1.

[0039] In this embodiment, the catalyst to be regenerated is subjected to a hydrogenation regeneration reaction, and the conditions for the hydrogenation regeneration reaction are selected so that the hydrogen donor to be regenerated can be regenerated; the regenerated hydrogen donor is returned to the slurry bed reactor to continue to participate in the hydrogen transfer reaction, so that the hydrogen donor can be recycled and the economic benefit can be improved.

[0040] In one embodiment, the flow ratio of the regenerated hydrogen donor to the fresh hydrogen donor returning to the slurry bed reactor is 0.1 to 99:1.

[0041] In one embodiment, the method further comprises: sending another portion of the unconverted oil out of the system.

[0042] In one embodiment, if Figure 1 As shown, a specific method for hydrogenating heavy crude oil in a liquid phase non-hydrogen slurry bed comprises:

[0043] The raw oil 10, the hydrogen supply agent 11 and the catalyst 12 are mixed and then introduced into the slurry bed reactor A for hydrogen transfer reaction to obtain the hydrogen transfer reaction product 13. The hydrogen transfer reaction product is passed through the separation tower B to obtain the gas phase light component 14, the mixed light oil 15, the heavy oil product 16, the unconverted oil 18, and the catalyst-containing circulating unconverted oil 17. The catalyst-containing circulating unconverted oil 17 is returned to the inlet of the slurry bed reactor 1. The mixed light oil 15 is separated through the fractionation tower 2 to obtain the product light oil 21 and the hydrogen supply agent 20 to be generated; the hydrogen supply agent 20 to be generated is then sent to the hydrogen supply agent regeneration unit 3 for hydrogenation regeneration treatment, and the obtained regenerated hydrogen supply agent 22 is returned to the slurry bed reactor A for recycling.

[0044] The second aspect of the present disclosure provides a system for hydrogenating heavy crude oil in a liquid phase non-hydrogenated slurry bed, the system comprising: a slurry bed reactor, a first separation device, a second separation device and a hydrogen supply agent regeneration unit; the slurry bed reactor comprises a mixed raw material inlet and a hydrogen transfer product outlet; the first separation device comprises a hydrogen transfer product inlet, a gas phase outlet, a mixed light oil outlet, a heavy oil product outlet and an unconverted oil outlet; the second separation device comprises a mixed light oil inlet, a hydrogen supply agent outlet to be generated and a product light oil outlet; the hydrogen supply agent regeneration unit comprises a hydrogen supply agent inlet to be generated, a hydrogen inlet and a regenerated hydrogen supply agent outlet; the hydrogen transfer product outlet of the slurry bed reactor is connected to the hydrogen transfer product inlet of the first separation device, so that the hydrogen transfer product generated by the hydrogen transfer reaction enters the first separation device for first separation; the unconverted oil outlet of the first separation device is connected to the circulating pipeline through the circulating pipeline. The mixed raw material inlet of the slurry bed reactor is connected so that the unconverted oil containing the catalyst can enter the slurry bed reactor to continue the hydrogen transfer reaction; the mixed light oil outlet of the first separation device is connected with the mixed light oil inlet of the second separation device, which is used to send the mixed light oil separated by the first separation device to the second separation device for separation again; the hydrogen supply agent outlet to be generated of the second separation device is connected with the hydrogen supply agent inlet to be generated of the hydrogen supply agent regeneration unit, so that the hydrogen supply agent to be regenerated can enter the hydrogen supply agent regeneration unit for regeneration reaction; the regenerated hydrogen supply agent outlet of the hydrogen supply agent regeneration unit is connected with the mixed raw material inlet of the slurry bed reactor, so that the regenerated hydrogen supply agent can return to the slurry bed reactor to continue to participate in the hydrogen transfer reaction; wherein, the hydrogen inlet of the hydrogen supply agent regeneration unit is connected with the regeneration source, which is used to pass hydrogen into the hydrogen supply agent regeneration unit to participate in the regeneration reaction.

[0045] In one embodiment, one or more heat exchangers are provided in the system to fully exchange heat between the logistics in the system and reduce the amount of heating medium. Similarly, one or more pumps are provided in the system, for example, a heat exchanger and a pump are provided on the mixed raw material inlet pipeline of the slurry bed reactor.

[0046] In one embodiment, the unconverted oil outlet of the first separation device is also led out of the system through a product pipeline for other treatment or scrapping.

[0047] The present disclosure is further illustrated below by way of examples, but the present disclosure is not limited thereby.

[0048] Example 1

[0049] Use Figure 1 The system and method shown are used to hydrotreat heavy crude oil, specifically:

[0050] 100 t / h of raw oil 10 (atmospheric residue), hydrogen donor 11 (cyclohexane, 100 t charged at one time, 7.2 t / h flow rate after stabilization) and catalyst 12 (oil-soluble organic homogeneous molybdenum catalyst, 2 t charged at one time, 0.2 t / h flow rate after stabilization) are mixed, pressurized and heated to 40 barg and 425°C, and then sent to slurry bed reactor A for hydrogen transfer reaction. After the reaction, the reactor is cooled to 350°C by heat exchange in a cooler, and then sent to separation tower B for separation to obtain gas phase light component 14 (distillation range <60°C), mixed light oil 15 (distillation range 60-350°C), heavy oil product 16 (distillation range 350-520°C), catalyst-containing circulating unconverted oil 17 (distillation range >520°C) and unconverted oil 18. The mixed light oil 15 is further separated by the fractionation tower 2 to obtain the product light oil 21 (distillation range is 60-100°C) and the hydrogen supply agent 20 to be generated, and the hydrogen supply agent 20 to be generated is sent to the hydrogen supply agent regeneration unit 3 for hydrogenation reaction, and the reaction conditions are: 200°C, 30bar, and the hydrogenation catalyst is a Pt-based solid catalyst, and the regenerated hydrogen supply agent 22 is returned to the slurry bed reactor A, and the flow rate after stable operation is 0.8t / h. Among them, the properties of the raw oil 10 are shown in Table 1; the properties of the product oil are shown in Table 2.

[0051] Table 1 Raw oil properties

[0052] index Numeric <![CDATA[Density (20 °C) / (g / cm 3 )]]> 1073 Viscosity (20℃) / (mPa·s) 900 Sulfur wt% 3.6 Ni(ppm) 41 V(ppm) 108 Asphaltene wt% 11

[0053] Comparative Example 1

[0054] The crude oil, catalyst and hydrogen were pressurized and heated to 40 barg and 425°C respectively and then sent into a slurry bed reactor for hydrogenation reaction. The product indicators obtained are shown in Table 2.

[0055] Table 2 Product properties of Example 1 and Comparative Example 1

[0056]

[0057] According to the comparison of the data in Example 1 and Comparative Example 1 in Table 2, it can be seen that the method of the present invention can improve the yield of liquid products, reduce coking, and reduce the pressure of the reaction system, thereby improving the safety of the method, compared with the traditional method of using hydrogen to hydrogenate heavy crude oil.

[0058] The preferred embodiments of the present disclosure are described in detail above in conjunction with the accompanying drawings; however, the present disclosure is not limited to the specific details in the above embodiments. Within the technical concept of the present disclosure, a variety of simple modifications can be made to the technical solution of the present disclosure, and these simple modifications all fall within the protection scope of the present disclosure.

[0059] It should also be noted that the various specific technical features described in the above specific embodiments can be combined in any suitable manner without contradiction. In order to avoid unnecessary repetition, the present disclosure will not further describe various possible combinations.

[0060] In addition, various embodiments of the present disclosure may be arbitrarily combined, and as long as they do not violate the concept of the present disclosure, they should also be regarded as the contents disclosed by the present disclosure.

Claims

1. A method for hydrogenating heavy crude oil in a liquid phase non-hydrogen slurry bed, characterized in that: The method includes: The raw oil, the catalyst and the hydrogen donor are mixed and then introduced into a slurry bed reactor for hydrogen transfer reaction to obtain a hydrogen transfer reaction product; The hydrogen transfer reaction product is subjected to a first separation to obtain a gas phase light component, mixed light oil, heavy oil product and unconverted oil containing a catalyst; a portion of the unconverted oil is returned to the slurry bed reactor to continue the reaction; The mixed light oil is subjected to a second separation to obtain product light oil and a hydrogen supply agent to be produced; The hydrogen transfer reaction conditions include: reaction temperature of 420-430° C., reaction pressure of 35-50 bar, reaction time of 0.5-2.5 h, and the ratio of the feedstock oil to the hydrogen donor is 2-5; The fraction cut point between the gas phase light component and the mixed light oil is 40-60°C, the fraction cut point between the mixed light oil and the heavy oil product is 300-360°C, and the fraction cut point between the heavy oil product and the unconverted oil is 480-540°C; The second separation is carried out in a fractionation tower, and the cut-off point of the product light oil and the hydrogen donor to be produced is 130-160°C; The hydrogen donor is selected from one or more of cyclohexane, cyclohexene, cyclohexadiene and methylcyclohexane.

2. The method according to claim 1, characterized in that The raw oil is selected from one or more of vacuum residue oil, deasphalted oil, atmospheric residue oil, crude oil fractions with an initial boiling point greater than 350°C, and extra-thick crude oil; The hydrogen donor is cyclohexane; The catalyst is selected from one or more of an oil-soluble catalyst, a supported nickel-molybdenum powder catalyst, a non-precious metal catalyst and a precious metal solid catalyst; The non-precious metal in the non-precious metal catalyst includes one or more of nickel, molybdenum and iron, and the precious metal in the precious metal solid catalyst includes one or more of platinum, gold, silver, ruthenium, rhodium and palladium.

3. The method according to claim 2, characterized in that The catalyst is an oil-soluble organic homogeneous molybdenum catalyst.

4. The method according to claim 1, characterized in that The method further comprises: contacting the hydrogen supply agent to be regenerated with hydrogen to carry out a hydrogenation regeneration reaction, and returning the obtained regenerated hydrogen supply agent to the slurry bed reactor for cyclic use.

5. The method according to claim 4, characterized in that The conditions of the hydrogenation regeneration reaction include: a reaction temperature of 150-250° C., a reaction pressure of 5-50 bar, and a volume ratio of the hydrogen gas to the hydrogen supply agent to be generated of (0.1-999):

1.

6. The method according to claim 5, characterized in that The conditions of the hydrogenation regeneration reaction include: a reaction temperature of 180-220° C. and a reaction pressure of 25-35 bar.

7. The method according to claim 1, characterized in that The method also includes sending another portion of the unconverted oil out of the system.

8. A system for hydrogenating heavy crude oil in a liquid phase non-hydrogen slurry bed using the method according to any one of claims 1 to 7, characterized in that: The system comprises: a slurry bed reactor, a first separation device and a second separation device; The slurry bed reactor comprises a mixed feed inlet and a hydrogen transfer product outlet; The first separation device comprises a hydrogen transfer product inlet, a gas phase outlet, a mixed light oil outlet, a heavy oil product outlet and an unconverted oil outlet; The second separation device comprises a mixed light oil inlet, a hydrogen supply agent outlet and a product light oil outlet; The hydrogen transfer product outlet of the slurry bed reactor is connected to the hydrogen transfer product inlet of the first separation device; the unconverted oil outlet of the first separation device is connected to the mixed raw material inlet of the slurry bed reactor through a circulation pipeline; the mixed light oil outlet of the first separation device is connected to the mixed light oil inlet of the second separation device.

9. The system according to claim 8, characterized in that The hydrogen supply agent regeneration unit comprises an inlet for the hydrogen supply agent to be regenerated, an inlet for hydrogen gas and an outlet for the regenerated hydrogen supply agent; The outlet of the hydrogen supply agent to be generated of the second separation device is communicated with the inlet of the hydrogen supply agent to be generated of the hydrogen supply agent regeneration unit; the outlet of the regenerated hydrogen supply agent of the hydrogen supply agent regeneration unit is communicated with the mixed raw material inlet of the slurry bed reactor; The unconverted oil outlet of the first separation device is also led out of the system through a product line.

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