Shale oil layer oil and gas production simulation evaluation device

Abstract

The shale oil layer oil and gas exploitation simulation evaluation device of the present invention relates to the field of shale oil exploitation simulation technology, including a nitrogen injection system, a liquid injection system, a shale model body, a temperature control module, a pressure control module, a product collection and metering system and a vacuum system. The device adopts a modular design. When the oil shale in the high-pressure core tube produces shale oil and gas at a certain temperature, the nitrogen injection system purges the oil and gas in the model and accurately meters the injected nitrogen; the liquid injection system can realize the injection of a certain amount of water, chemical agent or catalyst solution into the high-pressure core tube; the temperature control module can set the experimental temperature and detect the temperature of the high-pressure core tube, the shell high-pressure chamber and the output end at the same time; the pressure control module can set the experimental pressure and detect the pressure of the high-pressure core tube, the shell high-pressure chamber and the output end at the same time; the product collection and metering system cools the output, separates the output liquid and gas, and accurately meters and analyzes the output liquid and gas.

Description

Technical Field

[0001] The present invention relates to the technical field of shale oil production simulation, and in particular to a shale oil layer oil and gas production simulation evaluation device. Background Art

[0002] In recent years, Daqing Oilfield is in the transition stage from conventional oil and gas exploration and development to unconventional oil and gas exploration and development. The medium and low maturity shale oil resources are rich, with an estimated resource volume of more than 20 billion tons, which is the resource guarantee for the sustainable development of Daqing Oilfield. Oil shale (also known as kerogen shale) is a high-ash sedimentary rock containing combustible organic matter. The main difference between it and coal is that the ash content exceeds 40%, and the main difference from carbonaceous shale is that the oil content is greater than 3.5%. Oil shale is an unconventional oil and gas resource, and is listed as a very important successor energy in the 21st century due to its rich resources and feasibility of development and utilization. Shale oil and gas refers to the oil and gas resources contained in the oil shale formation dominated by shale, including oil in the pores and cracks of mud shale, and also including oil resources in the adjacent layers and interlayers of dense carbonate or clastic rocks in the mud shale formation. The oil reservoir quality of oil shale is poor, the heterogeneity is strong, and the fluid permeability is extremely poor. Therefore, in-depth research on the development mechanism of shale oil and indoor physical simulation evaluation research is the key to breakthroughs in shale oil development technology, which is of great significance to the effective large-scale utilization of shale oil.

[0003] At present, the determination of oil and gas content in oil shale is mainly based on the requirements of the Petrochemical Industry Standard of the People's Republic of China "Oil Shale Oil Content Determination Method (Low-temperature Distillation Method)" SH / T0508-92. This method can effectively give the gaseous hydrocarbon content (S0) and liquid hydrocarbon content (S1) in oil shales of different occurrences. However, it has considerable limitations in accurately studying the oil and gas production of oil shale at different temperatures under reservoir pressure conditions, the oil and gas production after pyrolysis of organic kerogen (S2), and the oil production evaluation when different oil washing media and catalysts are added at different temperatures under reservoir conditions.

[0004] Therefore, there is an urgent need for an oil and gas production evaluation device for oil shale at different temperatures under formation pressure to solve the above problems. Summary of the invention

[0005] In view of the deficiencies in the prior art, the present invention provides a shale oil layer oil and gas production simulation evaluation device.

[0006] The shale oil layer oil and gas exploitation simulation evaluation device of the present invention comprises a nitrogen injection system, a liquid injection system, a shale model body, a temperature control module, a pressure control module, a product collection and metering system and a vacuum system. The shale model body is composed of a high-pressure core tube with an independent pipe coaxially arranged in a closed shell high-pressure chamber; the front pipeline of the shale model body is connected to the nitrogen injection system and the liquid injection system, and the rear pipeline of the shale model body is connected to the product collection and metering system; the vacuum system pipeline is connected to the outlet pipeline of the nitrogen injection system and the inlet pipeline of the high-pressure core tube, and the shell high-pressure chamber venting pipeline; the temperature control module is composed of a PC combined with various temperature sensors, power supply control of the electric heater, and medium flow control of the cooler arranged in the device; the pressure control module is composed of a PC combined with a pressure sensor, a gas flow controller, a flow regulating valve, a back pressure valve, a venting valve, a pressure setting control and a pressure chamber safety valve arranged in the device.

[0007] As a further improvement of the present invention, the nitrogen injection system is composed of a booster pump connected to two parallel nitrogen tanks via a pipeline, and its outlet pipeline is connected to the inlet end of the high-pressure core tube of the shale model body via a primary pressure regulating valve, a secondary pressure regulating valve and a gas flow meter.

[0008] As a further improvement of the present invention, the liquid injection system is composed of an injection pump pipeline connected to two parallel piston containers, and its outlet pipeline is connected to the inlet end of the high-pressure core tube of the shale model body through a pressure sensor I.

[0009] As a further improvement of the present invention, the product collection and metering system is composed of an outlet pipeline of the high-pressure core tube in the shale model body entering a cooler through a back pressure controller, a top outlet pipeline of the cooler is connected to the middle of a gas drying separator, and a top outlet pipeline of the gas drying separator enters a gas metering tank through a gas collection pump, a gas sampling valve is provided at the bottom of the tank, and a liquid sampling valve is provided at the bottom of the cooler.

[0010] As a further improvement of the present invention, the vacuum system is formed by connecting the inlet pipe of the vacuum pump to the pipelines of the nitrogen injection system and the high-pressure core tube and the shell high-pressure chamber venting pipeline respectively.

[0011] As a further improvement of the present invention, the temperature control module uses a PC as a central processor to collect signals from five temperature sensors evenly distributed throughout the high-pressure core tube, and feedback-adjusts the control signals sent by the multi-channel electric heating rings on the high-pressure core tube and the water cooling system in the shell high-pressure chamber.

[0012] As a further improvement of the present invention, the pressure control module uses a PC as a central processor to collect pressure signals of three-stage pressure sensor II provided on the shale model body, pressure sensor III on the nitrogen tank outlet pipeline, pressure sensor I on the piston container outlet pipeline, high-pressure core tube outlet pressure sensor IV, and back pressure valve pressure sensor V, and feeds back system control work instruction signals to the nitrogen primary pressure regulating valve and secondary pressure regulating valve, liquid injection pump, pressure chamber safety valve on the shale model body, and back pressure controller.

[0013] As a further improvement of the present invention, the vent pipeline at the front end of the shell high-pressure chamber is the vent port of the shell high-pressure chamber, which is connected to the outlet valve of the booster pump through a valve to form a nitrogen direct pressurization pipeline for the shell high-pressure chamber.

[0014] As a further improvement of the present invention, a hand pump is connected to the side line of the back pressure controller, forming an auxiliary back pressure regulating mechanism for the outlet of the high-pressure core tube.

[0015] The shale oil layer oil and gas exploitation simulation evaluation device of the present invention adopts a modular design. When the oil shale in the high-pressure core tube produces shale oil and gas at a certain temperature, the nitrogen injection system blows the oil and gas in the model and accurately measures the injected nitrogen. The liquid injection system can inject a certain amount of water, chemical agent or catalyst solution into the high-pressure core tube. 5 to 10 kg of oil shale can be loaded into the high-pressure core tube in the shale model body. Since the amount of oil shale loaded into the core tube is sufficient, the output metering error can be greatly reduced. Five temperature sensors and three pressure sensors II are designed to be evenly distributed in the high-pressure core tube, which can effectively monitor the temperature and pressure in the high-pressure core tube. The experimental temperature and pressure setting control is based on the temperature and pressure sensors. The annular electric heating ring fastened outside the high-pressure core tube provides the experimental temperature for the core in the tube. The temperature setting of this design is flexible and can achieve long-term constant setting of a certain temperature point. After this temperature experiment, the temperature setting of the next temperature point can be carried out continuously; there is circulating water in the cooling water coil in the shell high-pressure chamber during the experiment, which can prevent the pressure chamber body and the nitrogen filled inside from being too hot; the temperature control module can set the experimental temperature and detect the temperature of the high-pressure core tube, shell high-pressure chamber and output end at the same time; the pressure control module can set the experimental pressure and detect the pressure of the high-pressure core tube, shell high-pressure chamber and output end at the same time; the product collection and metering system cools the output, separates the output liquid and gas, and accurately measures and analyzes the output liquid and gas. BRIEF DESCRIPTION OF THE DRAWINGS

[0016] Figure 1 It is a structural flow chart of the present invention;

[0017] Figure 2 This is a schematic diagram of the structure of the shale model body of this device. DETAILED DESCRIPTION

[0018] like Figure 1 As shown, the shale oil layer oil and gas production simulation evaluation device of the present invention includes a nitrogen injection system 1, a liquid injection system 2, a shale model body 3, a temperature control module 4, a pressure control module, a product collection and metering system 6 and a vacuum system 7.

[0019] The nitrogen injection system 1 is composed of a booster pump 10 connected to two parallel nitrogen tanks 11 via a pipeline, and its outlet pipeline is connected to the inlet end of the high-pressure core tube 9 of the shale model body 3 via a primary pressure regulating valve 12, a secondary pressure regulating valve 13 and a gas flow meter 14.

[0020] The liquid injection system 2 is composed of an injection pump 15 pipeline connected to two parallel piston containers 16, and its outlet pipeline is connected to the inlet end of the high-pressure core tube 9 of the shale model body 3 through a pressure sensor I 17.

[0021] The shale model body 3 is composed of a high-pressure core tube 9 with an independent pipe line coaxially arranged in a closed shell high-pressure chamber 8; the front pipeline of the shale model body 3 is connected to the nitrogen injection system 1 and the liquid injection system 2, and the rear pipeline of the shale model body 3 is connected to the product collection and metering system 6; an electric heating ring 28 is provided on the outer wall of the high-pressure core tube 9, and a water cooling system 29 is surrounded on the inner wall of the shell high-pressure chamber 8. A movable seat 40 of the shale model body 3 is provided on the shell high-pressure chamber 8, such as Figure 2 shown.

[0022] The temperature control module 4 uses a PC as a central processor to collect signals from five temperature sensors 27 evenly distributed throughout the high-pressure core tube 9, and feedbacks and adjusts the control signals sent by the multi-channel electric heating ring 28 on the high-pressure core tube 9 and the water cooling system 29 in the shell high-pressure chamber 8.

[0023] The pressure control module uses a PC as a central processor to collect pressure signals of three-stage pressure sensors II30 provided on the shale model body 3, pressure sensor III31 on the outlet pipeline of the nitrogen tank 11, pressure sensor I17 on the outlet pipeline of the piston container 16, pressure sensor IV32 at the outlet of the high-pressure core tube 9, and pressure sensor V33 of the back pressure valve, and feeds back system control work instruction signals to the first-stage nitrogen pressure regulating valve 12 and the second-stage pressure regulating valve 13, the liquid injection pump 15, the pressure chamber safety valve 34 on the shale model body 3, and the back pressure controller 18.

[0024] The product collection and metering system 6 is composed of an outlet pipeline of the high-pressure core tube 9 in the shale model body 3 entering a cooler 19 through a back pressure controller 18, a top outlet pipeline of the cooler 19 connected to the middle of a gas drying separator 20, and a top outlet pipeline of the gas drying separator 20 entering a gas metering tank 22 through a gas collection pump 21, a gas sampling valve 23 is provided at the bottom of the tank, a liquid sampling valve 24 is provided at the bottom of the cooler, and a hand pump 37 is connected to the side line of the back pressure controller 18, forming an auxiliary back pressure control mechanism for the outlet of the high-pressure core tube 9.

[0025] The vacuum system 7 is formed by connecting the inlet pipe of the vacuum pump 25 to the pipelines of the nitrogen injection system 1 and the high-pressure core tube 9 and the venting pipeline 26 of the shell high-pressure chamber 8 respectively.

[0026] The vent pipe 26 at the front end of the shell high-pressure chamber 8 is the vent port of the shell high-pressure chamber 8 , which is connected to the outlet valve 36 of the booster pump 10 through a valve 35 to form a nitrogen direct pressurization pipeline for the shell high-pressure chamber 8 .

[0027] This device provides a set of physical simulation experimental devices for evaluating the oil and gas production of oil shale at different temperatures under simulated formation pressure, as well as the oil and gas production when different oil washing media and catalysts are added at different temperatures. This device can evaluate the oil and gas production of high-temperature distillation of oil shale at different temperature points under formation pressure conditions; it can evaluate the oil and gas production of oil shale injected with water (steam) at different temperatures under formation pressure conditions; it can study the change of oil production temperature with and without catalyst under formation pressure conditions; it can study the change of pyrolysis temperature of organic kerogen in oil shale with different catalysts added under formation pressure conditions; it can evaluate the oil and gas production with different catalysts added at the same temperature under formation pressure conditions; it can evaluate the oil and gas production with the same catalyst added at different temperatures under formation pressure conditions; it can evaluate the oil and gas production with different catalysts added at the same temperature under formation pressure conditions; it can evaluate the oil and gas production with different catalysts added at the same temperature under formation pressure conditions; it can evaluate the oil and gas production with different catalysts added under formation pressure conditions.

[0028] The physical simulation experimental process for evaluating the oil and gas production of oil shale at different temperatures under formation pressure mainly includes three processes: see the following experimental processes Ⅰ~Ⅲ.

[0029] Experimental process I: It is a physical simulation experimental process for evaluating the oil and gas output of high-temperature distillation at different temperature points or distillation with the addition of solid catalyst under oil shale formation pressure conditions.

[0030] The vacuum pump 25 is connected to two nitrogen cylinders 11, and the vacuum is applied for 4 hours. The high-purity nitrogen source is connected to the booster pump 10, and high-purity nitrogen is injected into the two nitrogen cylinders 11. The pressure sensor III 31 shows that the pressure is 5 to 10 MPa higher than the experimental pressure. The first-level pressure regulating valve 12, the second-level pressure regulating valve 13 and the gas flow meter 14 are debugged, and the nitrogen flow rate is adjusted to the experimental state through the flow regulating valve 38. The back pressure of the back pressure controller 18 is set to be consistent with the experimental pressure by using the hand pump 37 and the buffer tank 39. In the design of the high-pressure core tube 9 Install 3 pressure sensors II 30 and 5 temperature sensors 27 at the position, fill about 8 kg of oil shale mixed with catalyst into the high-pressure core tube 9, and seal and evacuate for at least 4 hours; fix the 20-way electric heating ring 28 on the outer wall of the high-pressure core tube 9, put the high-pressure core tube 9 into the specified position of the shell high-pressure cabin 8 along the model tube slide of the shell high-pressure cabin 8, connect the temperature setting control and pressure setting control, and close the shell high-pressure cabin 8; connect the vent valve 35 and the vacuum system 7, and seal the shell high-pressure cabin 8 to evacuate to at least 4 hours; the vent valve 35 is connected to the booster pump 10, and high-purity nitrogen is pumped into the pressure chamber to increase the pressure to the set experimental (formation) pressure, and the pressure of the pressure chamber safety valve 34 is adjusted to be consistent with the experimental set pressure; the experimental temperature and pressure are set by the temperature setting control and pressure setting control programs, and the experiment begins; the pressure chamber water cooling system 29 is opened to make the outer wall temperature of the pressure chamber not exceed 100°C. When the constant temperature time of a certain set experimental temperature reaches the requirement, the first-level pressure regulating valve 12 and the second-level pressure regulating valve 13 are opened in sequence to blow out the oil and gas in the high-pressure core tube 9, and enter the product collection and metering system 6 through the back pressure controller 18; first to the cooler 19, condensed by the cooling system 39, the temperature of the condensed output liquid is shown to be lower than 50°C, the liquid sampling valve 24 takes out the output liquid, and the liquid production, oil production and chemical composition are measured; the gas enters the gas drying separator 20, and the gas after drying enters the gas collection pump 21, and the flow of the output gas is measured by the automatic gas metering cylinder 22, and the gas sample is taken out by the gas sampling valve 23 to analyze the output gas composition. The above is the physical simulation experimental process for evaluating the oil and gas output by high-temperature distillation at different temperature points or by distillation with the addition of a solid catalyst under oil shale formation pressure conditions.

[0031] Experimental process II: It is a physical simulation experimental process for evaluating the oil and gas production from high-temperature steam distillation at different temperature points under oil shale formation pressure conditions.

[0032] Use a hand pump 37 and a buffer tank 39 to set the back pressure of the back pressure controller 18 to be consistent with the experimental pressure; install three pressure sensors II 30 and five temperature sensors 27 at the designed position of the high-pressure core tube 9, fill about 8 kg of oil shale into the high-pressure core tube 9, seal and evacuate for at least 4 hours, and then saturate the high-pressure core tube 9 filled with oil shale after evacuation with experimental water; fix the 20-way electric heating ring 28 on the outer wall of the high-pressure core tube 9, put the high-pressure core tube 9 into the designated position of the shell high-pressure cabin 8 along the model pipe slide of the shell high-pressure cabin 8, connect the temperature setting control and the pressure setting control, and close the shell high-pressure cabin 8; connect the vent valve 35 and the vacuum system 7, seal and evacuate the shell high-pressure cabin 8 for at least 4 hours; connect the vent valve 35 to the booster pump 10, pump high-purity nitrogen into the pressure cabin to increase the pressure to the set experimental (formation) pressure, and adjust the pressure of the pressure cabin safety valve 34 to the experimental setting The set pressure is consistent; the high-pressure core tube 9 is connected to the injection pump 15 through the injection pressure sensor Ⅰ17, and the experimental temperature and pressure are set through the temperature setting control and pressure setting control program, and the experiment begins; the pressure chamber water cooling system 29 is turned on to make the temperature of the outer wall of the pressure chamber not exceed 100°C during the experiment. When a certain set experimental temperature constant temperature time reaches the requirement, the injection pump 15 is turned on to blow out the oil and gas in the high-pressure core tube 9, and enter the product collection and metering system 6 through the back pressure controller 18; first to the cooler 19, condensed by the cooling system 39, the temperature of the condensed output liquid is shown to be lower than 50°C, the liquid sampling valve 24 takes out the output liquid, and the liquid production, oil production and chemical composition are measured; the gas enters the gas drying separator 20, and the gas after drying enters the gas collection pump 21, and the flow of the output gas is measured by the automatic gas metering cylinder 22, and the gas sample is taken out by the gas sampling valve 23 to analyze the output gas composition. The above is the physical simulation experiment process for evaluating the output oil and gas volume of high-temperature steam distillation at different temperature points under the pressure conditions of oil shale formations.

[0033] Experimental process III: It is a physical simulation experimental process for evaluating the oil and gas production by injecting chemical agents and catalyst solutions at different temperature points under oil shale formation pressure conditions.

[0034] Use a hand pump 37 and a buffer tank 39 to set the back pressure of the back pressure controller 18 to be consistent with the experimental pressure; install three pressure sensors II 30 and five temperature sensors 27 at the designed position of the high-pressure core tube 9, fill about 8 kg of oil shale into the high-pressure core tube 9, seal and evacuate for at least 4 hours, and then saturate the high-pressure core tube 9 filled with oil shale after evacuation with a saturated experimental chemical solution or catalyst solution; fix the 20-way electric heating ring 28 on the outer wall of the high-pressure core tube 9, put the high-pressure core tube 9 into the specified position of the shell high-pressure cabin 8 along the model pipe slide of the shell high-pressure cabin 8, connect the temperature setting control and the pressure setting control, and close the shell high-pressure cabin 8; connect the vent valve 35 and the vacuum system 7, seal and evacuate the shell high-pressure cabin 8 for at least 4 hours; connect the vent valve 35 to the booster pump 10, pump high-purity nitrogen into the pressure cabin to increase the pressure to the set experimental (formation) pressure, and adjust the pressure of the pressure cabin safety valve 34 to The experimental setting pressure is consistent; the high-pressure core tube 9, piston container 16, and injection pump 15 are connected through the injection pressure sensor Ⅰ17; the experimental temperature and pressure are set through the temperature setting control and pressure setting control program, and the experiment begins; the pressure chamber water cooling system 29 is turned on to make the outer wall temperature of the pressure chamber not exceed 100°C during the experiment. When a certain set experimental temperature constant temperature time reaches the requirement, the injection pump 15 is turned on to blow out the oil and gas in the high-pressure core tube 9, and enter the product collection and metering system 6 through the back pressure controller 18; first to the cooler 19, condensed by the cooling system, the temperature of the condensed output liquid is shown to be lower than 50°C, the liquid sampling valve 24 takes out the output liquid, and the industrial volume, oil production and chemical composition are measured; the gas enters the gas drying separator 20, and the gas after drying enters the gas collection pump 21, and the flow of the output gas is measured by the automatic gas metering cylinder 22, and the gas sample is taken out by the gas sampling valve 23 to analyze the output gas composition. The above is the physical simulation experiment process for evaluating the output oil and gas volume of chemical agents and catalyst solutions injected at different temperature points under the pressure conditions of oil shale formations.

Claims

1. A shale oil layer oil and gas production simulation evaluation device, comprising a nitrogen injection system (1), a liquid injection system (2), a shale model body (3), a temperature control module (4), a pressure control module, a product collection and metering system (6) and a vacuum system (7), characterized in that: The shale model body (3) is composed of a high-pressure core tube (9) with an independent pipe passage coaxially arranged in a closed shell high-pressure chamber (8); the front pipeline of the shale model body (3) is connected to the nitrogen injection system (1) and the liquid injection system (2), and the rear pipeline of the shale model body (3) is connected to the product collection and metering system (6); the vacuum system (7) pipeline is connected to the outlet pipeline of the nitrogen injection system (1) and the inlet pipeline of the high-pressure core tube (9), and the venting pipeline (26) of the shell high-pressure chamber (8); the temperature control module (4) is composed of a PC combined with various temperature sensors, power supply control of the electric heater, and medium flow control of the cooler respectively arranged in the shale oil layer oil and gas production simulation evaluation device; the pressure control module is composed of a PC combined with the pressure sensor, gas flow controller, flow regulating valve (38), back pressure valve, vent valve, pressure setting control and pressure chamber safety valve arranged in the shale oil layer oil and gas production simulation evaluation device; The nitrogen injection system (1) is composed of a booster pump (10) connected to two parallel nitrogen tanks (11) via a pipeline, and the outlet pipeline of the nitrogen tank (11) is connected to the inlet end of the high-pressure core tube (9) of the shale model body (3) via a first-level pressure regulating valve (12), a second-level pressure regulating valve (13) and a gas flow meter (14); The liquid injection system (2) is composed of a liquid injection pump (15) pipeline connected to two parallel piston containers (16), and the outlet pipeline of the piston container (16) is connected to the inlet end of the high-pressure core tube (9) of the shale model body (3) through a pressure sensor I (17); The product collection and metering system (6) is composed of an outlet pipeline of a high-pressure core tube (9) in a shale model body (3) entering a cooler (19) via a back pressure controller (18), a top outlet pipeline of the cooler (19) connected to the middle of a gas drying separator (20), a top outlet pipeline of the gas drying separator (20) entering a gas metering tank (22) via a gas collection pump (21), a gas sampling valve (23) being provided at the bottom of the gas metering tank (22), and a liquid sampling valve (24) being provided at the bottom of the cooler; The pressure control module uses a PC as a central processor to collect pressure signals from three-stage pressure sensors II (30) provided on the shale model body (3), a pressure sensor III (31) on the outlet pipeline of the nitrogen tank (11), a pressure sensor I (17) on the outlet pipeline of the piston container (16), an outlet pressure sensor IV (32) of the high-pressure core tube (9), and a back pressure valve pressure sensor V (33), and respectively feeds back system control work instruction signals to the first-stage pressure regulating valve (12), the second-stage pressure regulating valve (13), the liquid injection pump (15), the pressure chamber safety valve (34) on the shale model body (3), and the back pressure controller (18).

2. The shale oil layer oil and gas production simulation evaluation device according to claim 1, characterized in that: The vacuum pumping system (7) is composed of connecting the inlet pipeline of the vacuum pump (25) to the pipeline between the nitrogen injection system (1) and the high-pressure core tube (9) and to the venting pipeline (26) of the shell high-pressure chamber (8).

3. The shale oil layer oil and gas production simulation evaluation device according to claim 1, characterized in that: The temperature control module (4) uses a PC as a central processor to collect signals from five temperature sensors (27) evenly distributed throughout the high-pressure core tube (9), and to provide feedback to adjust the control signals sent by the multi-channel electric heating ring (28) on the high-pressure core tube (9) and the water cooling system (29) in the shell high-pressure chamber (8).

4. The shale oil layer oil and gas production simulation evaluation device according to claim 1 or 2, characterized in that: The venting pipeline (26) at the front end of the shell high-pressure chamber (8) is the venting port of the shell high-pressure chamber (8), and is connected to the outlet valve (36) of the booster pump (10) through a valve (35) to form a nitrogen direct charging pipeline for the shell high-pressure chamber (8).

5. The shale oil layer oil and gas production simulation evaluation device according to claim 1, characterized in that: The back pressure controller (18) is connected to a hand pump (37) on the side line, thereby forming an auxiliary back pressure control system for the outlet of the high pressure core tube (9).

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