Downhole oil pipe in-situ repair tool testing device and testing method

Abstract

The invention belongs to the field of natural gas extraction, and particularly relates to an underground oil pipe in-situ repair tool testing device which comprises a simulation wellbore and an oil pipe body, sealing cavities are formed in the simulation wellbore and the oil pipe body, one end of the oil pipe body is installed in a wellbore cavity of the simulation wellbore to form an oil pipe body fixing end, and a leakage point is preset in the oil pipe body. An oil sleeve annulus for accommodating protection liquid is formed between the oil pipe body and the simulation wellbore, and the liquid level is higher than a leakage point; the first module is used for adjusting the annulus pressure of the oil sleeve, the second module is used for adjusting a second parameter in the oil pipe body, a feeding module communicated with the oil pipe body is arranged above the oil pipe body, and a tool used for repairing a leakage point is arranged in the feeding module. The movable end of the oil pipe body is connected with a power source used for providing tension and compression alternating loads in the pipe length direction of the oil pipe body. The device further comprises a first unit and a second unit used for monitoring a second parameter in the oil pipe body, real gas well oil pipe repairing operation can be simulated, and the effect after repairing can be effectively evaluated.

Description

Technical Field

[0001] This invention belongs to the field of natural gas extraction, and specifically relates to a testing device and method for in-situ repair tools for downhole tubing. Background Technology

[0002] As the core channel for natural gas extraction, oil pipelines are exposed to high temperature and high pressure environments, as well as fluid erosion and sand abrasion during long-term service. Damage to the pipeline body or couplings can easily occur, causing natural gas to leak out into the annulus, resulting in an abnormal rise in annulus pressure and the formation of annulus pressure.

[0003] Annular pressure in gas wells can cause the wellhead tubing and equipment to be subjected to complex loads, reducing their service life, posing significant safety hazards, and potentially leading to sudden accidents. The solution to annular pressure problems in gas wells lies in repairing damage to the leaking tubing or couplings to prevent further leakage under operating conditions. Existing downhole tubing in-situ repair technology primarily involves lowering a repair tool into the well. Once the tool reaches the location to be repaired, mechanical or chemical repair methods are used to fix the leak. After the repair is complete, the tool is retrieved, and the repaired tubing still meets production requirements.

[0004] This approach effectively avoids the high costs, high risks, and potential damage to the formation associated with moving tubing. Due to the high development difficulty of downhole in-situ repair technology, the current field repair failure rate is relatively high. The main reason for failure is that current repair tools are only tested on small samples indoors, making it difficult to replicate the real-world working conditions of high temperature, high pressure, and alternating loads. Summary of the Invention

[0005] To address the above problems, this invention proposes a downhole tubing in-situ repair tool testing device, comprising a simulated wellbore and a tubing body, both of which have sealed cavities inside. One end of the tubing body is installed inside the cavity of the simulated wellbore to form a fixed end of the tubing body, and a leak point is pre-set inside the tubing body. An annulus is formed between the tubing body and the simulated wellbore to accommodate protective fluid with the fluid level higher than the leak point.

[0006] It also includes a first module for adjusting the annular pressure of the oil casing and a second module for adjusting the second parameter in the tubing body. An insertion module connected to the tubing body is arranged above the tubing body, and a tool for repairing leaks is placed inside the insertion module. The movable end of the tubing body is connected to a power source for providing alternating tensile and compressive loads along the length of the tubing body.

[0007] It also includes a first unit for monitoring a first parameter within the annulus of the tubing casing and a second unit for monitoring a second parameter within the tubing body.

[0008] Preferably, the feeding module includes a sealing cylinder, a driving component, an upper connecting section, a lower connecting section, a test section, and a gate valve. A horizontal upper support plate is arranged above the oil pipe body, and a through hole is formed on the surface of the upper support plate. The lower end of the through hole is connected to the oil pipe body through the lower connecting section, and a test section is arranged between the oil pipe body and the lower connecting section. The upper end of the through hole is connected to the sealing cylinder through the upper connecting section. A tool is arranged inside the sealing cylinder cavity, and the upper end of the tool is connected to the driving component for providing linear reciprocating movement along the axis of the sealing cylinder. A gate valve is installed at the bottom of the sealing cylinder.

[0009] Preferably, the power source includes a hydraulic cylinder, a column, and a servo hydraulic system. A lower support plate is installed parallel to the upper support plate and located at the bottom of the simulated well. A hydraulic cylinder is installed on the lower support plate and is connected to the servo hydraulic system through a pipeline. The hydraulic cylinder is connected to one end of the column, and the other end of the column is connected to the upper support plate.

[0010] Preferably, the first module is a first pressure relief valve, which is installed on the wall of the simulated well, and the height of the first pressure relief valve is higher than the height of the protective fluid.

[0011] Preferably, the second module includes a pressure port, a booster pump, a nitrogen tank, a heater, and a second pressure relief valve. The pressure port is located on the wall of the oil pipe body and is connected to the booster pump and the nitrogen tank through a first pipeline. The heater is located below the oil pipe body, and the second pressure relief valve is installed at the upper connecting section.

[0012] Preferably, the first unit is an annular pressure-temperature gauge, which is installed on the top of the simulated wellbore.

[0013] Preferably, the second unit pressure-temperature gauge is mounted on the test section.

[0014] Preferably, the drive component includes a blowout preventer, a fixed pulley, a wire rope, and a winch. The blowout preventer is blocked at the opening of the sealing cylinder. One end of the wire rope is connected to the tool. The wire rope passes through the blowout preventer and is wound around the fixed pulley. The fixed pulley is located directly above the sealing cylinder, and the other end of the wire rope is wound around the winch.

[0015] Preferably, the simulated wellbore is a thick-walled casing, and a tubing seat is provided at the bottom of the inner wall of the thick-walled casing, on which the tubing body is installed.

[0016] Preferably, the tool is equipped with a straightener at both ends.

[0017] Preferably, a drain valve is provided at the bottom of the simulated well.

[0018] This invention claims a testing method using the aforementioned in-situ repair tool testing device for downhole tubing, comprising:

[0019] Confirm the first tensile strength of the tubing body, and confirm the first temperature and first pressure values ​​required for tool repair;

[0020] The second parameter of the second module connected to the oil pipe body is adjusted to the first temperature value and the first pressure value;

[0021] The feed module is activated to feed the tool into the tubing body;

[0022] Use the tool to repair the pre-defined leak point inside the oil pipe body, then remove the tool;

[0023] Adjust the pressure of the oil jacket annulus in the first module to the predetermined value;

[0024] Adjust the second module to rise to the second pressure value, maintain the pressure for a predetermined duration, and monitor the pressure value of the oil pipe body in the second unit;

[0025] The second module is adjusted to lower the pressure to the first value, and the power source is started to apply alternating tensile and compressive loads to the oil pipe body. After a predetermined number of cycles, the first unit monitors the annular pressure value of the oil casing to determine the repair effect.

[0026] This invention mainly simulates the annulus state of a gas well by setting up a simulated wellbore and tubing body. Furthermore, it sets up a first module and a second module to adjust the annulus pressure and the second parameter of the tubing body, respectively, to more realistically simulate the working environment of repair and post-repair testing of a real gas well tubing.

[0027] Based on this, tools are set up to repair leaks. A power source applies alternating tensile and compressive loads to the tubing body. The repair effect is judged by monitoring the first parameter in the annulus of the tubing sleeve and the second parameter in the tubing body through the first and second units, respectively.

[0028] This invention can simulate real gas well tubing repair operations and effectively evaluate the repair results. The test system has a wide range of variable parameters, allowing for the testing of tubing of different specifications, simulating different pressures and temperatures within the simulated wellbore, and applying different tensile and compressive loads and internal pressures to the repaired tubing. It also allows for effective evaluation of the repair effect, facilitating the assessment of the applicability and reliability of in-situ repair tools in the laboratory. This improves the success rate of tool application in actual field repairs and is of great significance and application value for the development of downhole simulated tubing repair technology and ensuring the integrity and safety of gas wells. This method effectively avoids the high costs, high risks, and potential formation damage associated with moving tubing strings.

[0029] Other features and advantages of the invention will be set forth in the following description, and will be apparent in part from the description, or may be learned by practicing the invention. The objects and other advantages of the invention may be realized and obtained by means of the structures pointed out in the description and the drawings. Attached Figure Description

[0030] To more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, the drawings described below are some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0031] Figure 1 A schematic diagram of a test device for an in-situ repair tool for downhole tubing according to the present invention is shown.

[0032] Figure 2 A schematic diagram of a testing method according to the present invention is shown;

[0033] Figure 3 This diagram illustrates the pressure change of the tubing body under the test pressure in an embodiment of the present invention.

[0034] Figure 4 This diagram illustrates the application of alternating tensile and compressive cyclic loads to the tubing body in an embodiment of the present invention.

[0035] Figure 5 This diagram illustrates the change in annular pressure of the tubing under alternating tensile and compressive cyclic loads applied to the tubing body in an embodiment of the present invention.

[0036] In the picture,

[0037] 1. Simulated well shaft; 11. Drain valve;

[0038] 2. Tubing body; 21. Tubing seat;

[0039] 3. Module One;

[0040] 41. Pressure port; 42. Booster pump; 43. Nitrogen tank; 44. Heater; 45. Second pressure relief valve;

[0041] 51. Sealing cylinder; 521. Blowout preventer; 522. Fixed pulley; 523. Wire rope; 524. Winch; 53. Upper connecting section; 54. Lower connecting section; 55. Test section; 56. Gate valve;

[0042] 6. Tools; 61. Straightener;

[0043] 71. Hydraulic cylinder; 72. Column; 73. Servo hydraulic system;

[0044] 8. Unit 1;

[0045] 9. Unit Two;

[0046] 100. Lower support plate; 101. Upper support plate. Detailed Implementation

[0047] To make the objectives, technical solutions, and advantages of the embodiments of the present invention clearer, the technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of the present invention, not all embodiments. Based on the embodiments of the present invention, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of the present invention.

[0048] refer to Figure 1 , Figure 1 This invention illustrates a downhole tubing in-situ repair tool testing device according to an embodiment of the present invention. The downhole tubing in-situ repair tool testing device includes a simulated wellbore 1 and a tubing body 2, both of which have sealed cavities inside. The simulated wellbore 1 is a thick-walled casing. A tubing seat 21 is provided at the bottom of the inner wall of the thick-walled casing, and the tubing body 2 is installed on the tubing seat 21.

[0049] Furthermore, a leak point is pre-set inside the tubing body 2. To facilitate faster simulation and repair experiments, artificial micro-defects can be created on the joints of the tubing body 2 to act as leak points. This method directly simulates the most common tubing joint leaks in gas wells. An annulus is formed between the tubing body 2 and the simulated wellbore 1 to accommodate protective fluid with a fluid level higher than the leak point.

[0050] The simulated wellbore 1 is equipped with a drain valve 11 at the bottom, which can drain the protective fluid in the annulus after the test.

[0051] The present invention also includes a first module 3 for adjusting the annular pressure of the oil sleeve and a second module for adjusting the second parameter inside the oil pipe body 2;

[0052] Furthermore, the second module includes a pressure port 41, a booster pump 42, a nitrogen tank 43, a heater 44, and a second pressure relief valve 45. The pressure port 41 is located on the wall of the tubing body 2, and the pressure port 41 is connected to the booster pump 42 and the nitrogen tank 43 through a first pipeline. The heater 44 is located below the tubing body 2. The second pressure relief valve 45 is installed at the upper connecting section 53 for adjusting the second parameter inside the tubing body 2.

[0053] The pressure port 41, booster pump 42 and nitrogen tank 43 in the second module are mainly used to adjust the pressure value inside the oil pipe body 2, while the heater 44 is mainly used to adjust the temperature value inside the oil pipe body 2.

[0054] Furthermore, the first module 3 is a first pressure relief valve, which is installed on the wall of the simulated wellbore 1, and the height of the first pressure relief valve is higher than the height of the protective fluid.

[0055] A feed module connected to the tubing body 2 is arranged above the tubing body 2, and a tool 6 for repairing leaks is placed inside the feed module. The feed module includes a sealing cylinder 51, a drive component, an upper connecting section 53, a lower connecting section 54, a test section 55, and a gate valve 56. A horizontal upper support plate 101 is arranged above the tubing body 2, with a through hole on the surface of the upper support plate 101. The lower end of the through hole is connected to the tubing body 2 via the lower connecting section 54, and a test section 55 is arranged between the tubing body 2 and the lower connecting section 54. The test section 55 is mainly used to test the passability of the tool 6. The upper end of the through hole is connected to the sealing cylinder 51 via the upper connecting section 53. The tool 6 is arranged inside the cavity of the sealing cylinder 51, and a stabilizer 61 is provided at both ends of the tool 6 to ensure the tool's stability. 6 The tool 6 is located in the center of the sealing cylinder 51 and the oil pipe body 2, and the upper end of the tool 6 is connected to a drive unit for providing linear reciprocating movement along the axis of the sealing cylinder 51. A gate valve 56 is installed at the bottom of the sealing cylinder 51.

[0056] The drive unit includes a blowout preventer 521, a fixed pulley 522, a wire rope 523, and a winch 524. The blowout preventer 521 is sealed at the opening of the sealing cylinder 51. The tool 6 is connected to one end of the wire rope 523. The wire rope 523 passes through the blowout preventer 521 and is wound around the fixed pulley 522. The fixed pulley 522 is located directly above the sealing cylinder 51, and the other end of the wire rope 523 is wound around the winch 524.

[0057] In actual operation, the winch 524 can be a high-power winch. By rotating the high-power winch, the wire rope 523 is released. After the wire rope 523 passes through the fixed pulley 522, the tool 6 at the bottom of the wire rope 523 enters the tubing body 2 through the through hole. When the gate valve 56 is closed, the feed module and the simulated wellbore 1 can be isolated, so that the tubing body 2 is in a closed environment. Thus, the test conditions can be adjusted through the simulated wellbore 1.

[0058] Of course, the gate valve 56 can be opened, and the high-power winch can be rotated in the opposite direction to retract the simulated wellbore 1 into the sealing cylinder 51.

[0059] The movable end of the tubing body 2 is connected to a power source for providing alternating tensile and compressive loads along the length of the tubing body 2. The power source includes a hydraulic cylinder 71, a column 72, and a servo hydraulic system 73. A lower support plate 100 is installed at the bottom of the simulated wellbore 1, parallel to the upper support plate 101. The hydraulic cylinder 71 is installed on the lower support plate 100, and the hydraulic cylinder 71 is connected to the servo hydraulic system 73 through a pipeline. The hydraulic cylinder 71 is connected to one end of the column 72, and the other end of the column 72 is connected to the upper support plate 101.

[0060] In actual operation, the servo hydraulic system 73 is started, driving the hydraulic cylinder 71 to move the upper support plate 101 installed on the column 72 up and down. The upper support plate 101 is connected to the movable end of the tubing body 2, and the fixed end of the tubing body 2 is fixed inside the simulated wellbore 1. Therefore, alternating tensile and compressive loads are generated on the tubing body 2.

[0061] The present invention also includes a first unit 8 for monitoring a first parameter in the annulus of the oil casing and a second unit 9 for monitoring a second parameter in the tubing body 2.

[0062] Unit 8 is an annular pressure and temperature gauge, which is installed on the top of the simulated wellbore 1.

[0063] Unit 2, 9. Pressure and temperature gauge, which is installed on test section 55.

[0064] This invention mainly simulates the annular state of a gas well by setting up a simulated wellbore 1 and a tubing body 2. Furthermore, it includes a first module. 3 The second module adjusts the annular pressure of the casing and the second parameter of the tubing body 2 respectively, to more realistically simulate the working environment of repair and post-repair testing of the real gas well tubing;

[0065] Based on this, tool 6 is set to repair the leak. The power source applies alternating tensile and compressive loads to the tubing body 2. The first parameter in the annulus of the tubing sleeve and the second parameter in the tubing body 2 are monitored by the first unit 8 and the second unit 9 respectively to judge the repair effect.

[0066] This invention can simulate real gas well tubing repair operations and effectively evaluate the repair results. The test system has many variable parameters, allowing for the testing of tubing bodies 2 of different specifications, simulating different internal pressures and temperatures within the simulated wellbore 1, and applying different tensile and compressive loads and internal pressures to the repaired tubing body 2. It can also effectively evaluate the repair effect, facilitating the evaluation of the applicability and reliability of in-situ repair tools in the laboratory, and improving the success rate of tool application in actual field repairs. This invention has significant meaning and application value for the development of downhole simulated tubing repair technology and ensuring the integrity and safety of gas wells. In this way, the high cost, high risk, and potential formation damage caused by moving the tubing string are effectively avoided.

[0067] refer to Figure 2 , Figure 2 A schematic diagram of a test method in an embodiment of the present invention is shown; the present invention claims a test method comprising:

[0068] In S1, the first tensile strength of the tubing body 2 is confirmed, and the first temperature value and first pressure value required for tool 6 to repair are confirmed.

[0069] In S2, the gate valve 56 is closed, the booster pump 42 and the nitrogen tank 43 are turned on to introduce nitrogen into the oil pipe body 2 for pressurization, and then the heater 44 is turned on to raise the temperature of the oil pipe body 2, so that the temperature and pressure inside the oil pipe body 2 are the first temperature value and the first pressure value.

[0070] In S3, the gate valve 56 is opened and the winch 524 is rotated to loosen the wire rope 523. After the wire rope 523 passes through the fixed pulley 522, the tool 6 at the bottom of the wire rope 523 enters the oil pipe body 2 along the through hole.

[0071] In S4, in-situ repair of downhole tubing is performed, which can be categorized according to tool type 6 as follows:

[0072] If it is a mechanical patching type in-situ repair tool: a patching material (such as an expansion tube) is patched onto the inner wall of the oil pipe at the leak point to be repaired using a special mechanical device;

[0073] If it is a chemical injection type in-situ repair tool: the sealing adhesive (such as resin) stored in the repair tool is applied to the inner wall of the oil pipe at the leak point to be repaired through the hydraulic injection mechanism;

[0074] After the repair is completed, rotate the winch 524 in the opposite direction to return the tool 6 to the sealing cylinder 51 and close the gate valve 56.

[0075] In S5, open the first pressure relief valve to release the pressure inside the annulus to zero;

[0076] In S6, the booster pump 42 and nitrogen tank 43 are turned on to introduce nitrogen into the oil pipe body 2 to pressurize it, causing the oil pipe body 2 to rise to the second pressure value. The pressure is maintained for a predetermined time, and the second unit 9 monitors the pressure value of the oil pipe body 2.

[0077] In S7, the second pressure relief valve 45 is opened to reduce the pressure value to the first pressure value. The servo hydraulic system 73 is started, and the hydraulic cylinder 71 drives the upper support plate 101 installed on the column 72 to move up and down. The upper support plate 101 is connected to the movable end of the tubing body 2, and the fixed end of the tubing body 2 is fixed inside the simulated wellbore 1. Therefore, a tensile and compressive alternating load is generated on the tubing body 2. After a predetermined number of cycles, the first unit 8 monitors the annular pressure value of the tubing and determines the repair effect.

[0078] Specific implementation examples are provided as follows:

[0079] 1) Determine the relevant parameters involved in tool 6: including the specifications, dimensions, steel grade, tensile strength N, pressure P, and temperature T of the tubing body 2 inside the simulated wellbore 1;

[0080] 2) Close the gate valve 56, open the nitrogen tank 42 and the booster pump 43 to introduce nitrogen into the oil pipe body 2 for pressurization, and turn on the heater 44 to raise the temperature of the oil pipe body 2 until the pressure and temperature in the oil pipe body 2 reach P and T respectively.

[0081] 3) Open the gate valve 56 and rotate the winch 524 to loosen the wire rope 523. After the wire rope 523 passes through the fixed pulley 522, the tool 6 at the bottom of the wire rope 523 enters the oil pipe body 2 through the through hole and reaches the leak point to be repaired.

[0082] 4) Tool 6 repairs the leak to be repaired. After repair, rotate the winch 524 in the opposite direction to lift tool 6 into the sealing cylinder 51 and close the gate valve 56.

[0083] 5) Open the second pressure relief valve 45 to reduce the pressure in the oil sleeve annulus to 0;

[0084] 6) Open the nitrogen tank 42 and the booster pump 43 to continuously pressurize the oil pipe body 2 until the pressure inside the oil pipe body 2 reaches the test pressure of 1.5P. Hold the pressure for 30 minutes. The second unit 9 monitors the pressure value of the oil pipe body 2.

[0085] 7) Adjust the pressure inside the oil pipe body 2 to P, start the servo hydraulic system 73, drive the hydraulic cylinder 71 to move up and down, apply alternating tensile and compressive cyclic loads to the oil pipe body 2, where the tensile load is 0.8N, the compressive load is 0.4N, the cycle is 20 times, and the first unit 8 monitors the annular pressure value of the oil sleeve; if the annular pressure reading of the oil sleeve continues to rise, and eventually rises to approximately P and remains balanced, it is determined that the repair has failed; otherwise, it is determined that the repair has succeeded.

[0086] The pressure changes within the tubing body 2 and the annulus pressure of the tubing body 2 are continuously monitored in Unit 9 and Unit 8, as follows:

[0087] refer to Figure 3 , Figure 3 A schematic diagram of the tubing pressure under the test pressure in an embodiment of the present invention is shown. In this schematic diagram, a rectangular coordinate system is established with time as the horizontal axis and the pressure inside the tubing body 2 as the vertical axis. It shows that in step 6), the initial pressure inside the tubing body 2 is P. After the pressure is increased to the test pressure of 1.5P, the pressure is maintained for 30 minutes. If the pressure does not increase and the pressure inside the annulus does not increase, then the repaired tubing passes the test in step 7.

[0088] refer to Figure 4 , Figure 4This invention illustrates a schematic diagram of applying alternating tensile and compressive cyclic loads to an oil pipe in an embodiment of the present invention. A rectangular coordinate system is established with time as the horizontal axis and the application of alternating tensile and compressive cyclic loads to the oil pipe as the vertical axis. In step 7), the curve above the origin 0 represents the change in tensile load, which is 0.8 N. The pressure inside the pipe is P. Each load application lasts for 10 minutes, and the cycle number is 10.

[0089] The curve located below the origin 0 represents the change in compressive load, which is 0.4N. The pressure inside the pipe is P. Each load is applied and held for 10 minutes, and the cycle is 10 times.

[0090] refer to Figure 5 , Figure 5 The diagram illustrates the change in annular pressure under alternating tension and compression loads applied to the tubing in an embodiment of the present invention. A rectangular coordinate system is established with time as the horizontal axis and annular pressure as the vertical axis. If the annular pressure remains at zero and does not increase further during the alternating tension and compression load test, it indicates that the downhole tubing has been successfully repaired in situ, as shown by the horizontal dashed line in the diagram.

[0091] Although the present invention has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that modifications can still be made to the technical solutions described in the foregoing embodiments, or equivalent substitutions can be made to some of the technical features; and these modifications or substitutions do not cause the essence of the corresponding technical solutions to deviate from the spirit and scope of the technical solutions of the embodiments of the present invention.

Claims

1. A testing device for in-situ repair tools of downhole tubing, characterized in that, It includes a simulated wellbore (1) and a tubing body (2) both of which have sealed cavities inside. One end of the tubing body (2) is installed inside the cavity of the simulated wellbore (1) to form a fixed end of the tubing body (2). A leak point is preset inside the tubing body (2). An annulus is formed between the tubing body (2) and the simulated wellbore (1) to accommodate protective fluid with the fluid level higher than the leak point. It also includes a first module (3) for adjusting the annular pressure of the oil casing and a second module for adjusting the second parameter inside the oil pipe body (2). An infeed module connected to the oil pipe body (2) is arranged above the oil pipe body (2), and a tool (6) for repairing leaks is placed inside the infeed module. The movable end of the oil pipe body (2) is connected to a power source for providing alternating tensile and compressive loads along the length of the oil pipe body (2). It also includes a first unit (8) for monitoring the first parameter in the annulus of the oil casing and a second unit (9) for monitoring the second parameter in the tubing body (2).

2. The downhole tubing in-situ repair tool testing device according to claim 1, characterized in that, The feeding module includes a sealing cylinder (51), a driving component, an upper connecting section (53), a lower connecting section (54), a test section (55), and a gate valve (56). A horizontal upper support plate (101) is arranged above the oil pipe body (2). The upper support plate (101) has a through hole on its surface. The lower end of the through hole is connected to the oil pipe body (2) through the lower connecting section (54). A test section (55) is arranged between the oil pipe body (2) and the lower connecting section (54). The upper end of the through hole is connected to the sealing cylinder (51) through the upper connecting section (53). A tool (6) is arranged inside the cylinder cavity of the sealing cylinder (51). The upper end of the tool (6) is connected to the driving component for providing linear reciprocating movement along the axis of the sealing cylinder (51). A gate valve (56) is installed at the bottom of the sealing cylinder (51).

3. The downhole tubing in-situ repair tool testing device according to claim 1, characterized in that, The power source includes a hydraulic cylinder (71), a column (72), and a servo hydraulic system (73). A lower support plate (100) is installed at the bottom of the simulated wellbore (1) parallel to the upper support plate (101). The hydraulic cylinder (71) is installed on the lower support plate (100), and the hydraulic cylinder (71) is connected to the servo hydraulic system (73) through a pipeline. The hydraulic cylinder (71) is connected to one end of the column (72), and the other end of the column (72) is connected to the upper support plate (101).

4. The downhole tubing in-situ repair tool testing device according to claim 1, characterized in that, The first module (3) is a first pressure relief valve, which is installed on the wall of the simulated wellbore (1), and the height of the first pressure relief valve is higher than the height of the protective fluid.

5. The downhole tubing in-situ repair tool testing device according to claim 1, characterized in that, The second module includes a pressure port (41), a booster pump (42), a nitrogen tank (43), a heater (44), and a second pressure relief valve (45). The pressure port (41) is located on the pipe wall of the oil pipe body (2), and the pressure port (41) is connected to the booster pump (42) and the nitrogen tank (43) through a first pipeline. The heater (44) is located below the oil pipe body (2), and the second pressure relief valve (45) is installed at the upper connecting short section (53).

6. The downhole tubing in-situ repair tool testing device according to claim 1, characterized in that, The first unit (8) is an annular pressure and temperature gauge, which is installed on the top of the simulated wellbore (1).

7. The downhole tubing in-situ repair tool testing device according to claim 1, characterized in that, The second unit (9) is a pressure-temperature gauge, which is mounted on the test section (55).

8. The downhole tubing in-situ repair tool testing device according to claim 2, characterized in that, The drive unit includes a blowout preventer (521), a fixed pulley (522), a wire rope (523), and a winch (524). The blowout preventer (521) is sealed at the opening of the sealing cylinder (51). The tool (6) is connected to one end of the wire rope (523). The wire rope (523) passes through the blowout preventer (521) and is wound around the fixed pulley (522). The fixed pulley (522) is located directly above the sealing cylinder (51), and the other end of the wire rope (523) is wound around the winch (524).

9. The downhole tubing in-situ repair tool testing device according to claim 3, characterized in that, The simulated wellbore (1) is a thick-walled casing, and a tubing seat (21) is provided at the bottom of the inner wall of the thick-walled casing. The tubing body (2) is installed on the tubing seat (21).

10. A testing device for in-situ repair tools of downhole tubing according to claim 2, characterized in that, The tool (6) is equipped with a straightener (61) at both ends.

11. The in-situ repair tool testing device for downhole tubing according to claim 3, characterized in that, A drain valve (11) is installed at the bottom of the simulated well shaft (1).

12. A testing method, using the in-situ repair tool testing device for downhole tubing as described in any one of claims 1-11, characterized in that, include: Confirm the first tensile strength of the tubing body (2), and confirm the first temperature value and first pressure value required for tool (6) repair; Adjust the second parameter of the second module to the oil pipe body (2) to the first temperature value and the first pressure value; The feed module is activated to feed the tool (6) into the tubing body (2); Tool (6) repairs the pre-set leak point inside the tubing body (2), and tool (6) is removed; Adjust the first module (3) until the annular pressure of the oil sleeve is at the predetermined value; Adjust the second module to rise to the second pressure value, maintain the pressure for a predetermined time, and the second unit (9) monitors the pressure value of the oil pipe body (2); Adjust the second module to the first pressure value, start the power source to apply tensile and compressive alternating load to the oil pipe body (2), cycle for a predetermined number of times, the first unit (8) monitors the annular pressure value of the oil sleeve, and determines the repair effect.

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