Lifting device and method for injection-production integrated concentric tube jet pump of immovable string

Abstract

The invention belongs to the technical field of underwater mining equipment, and particularly relates to an immovable string injection-production integrated concentric tube jet pump lifting device and method.The immovable string injection-production integrated concentric tube jet pump lifting device comprises an original well string, a working pump assembly and an inner pump cylinder assembly, and the original well string comprises an outer string and a safety valve; the working pump assembly is provided with a sealing cylinder, an oil pipe, an outer cylinder and a forced unlocking locking device integrated with a mandrel and a lock cylinder, the inner pump cylinder assembly is formed by sequentially connecting a pump cylinder, an upper plunger, a steam injection valve and a lower plunger, and the working pump assembly is connected with the inner pump cylinder assembly, then tripped into a preset position in an original well pipe column through the oil pipe and locked. The production technological processes such as heat injection, soaking, self-spraying and jet pump lifting can be sequentially completed without lifting or moving any tubular column during injection-production conversion, the deep sea thickened oil recovery operation process is effectively simplified, platform space occupation and operation time are remarkably reduced, the comprehensive cost is reduced, and the production efficiency is improved. And the operation safety and the system reliability are improved by reducing the operation times of the pipe column.

Description

Technical Field

[0001] This invention belongs to the technical field of underwater mining equipment, specifically relating to a concentric tube jet pump lifting device and method for integrated injection and extraction using a stationary tubing string. Background Technology

[0002] The continued growth in global energy demand is driving oil extraction activities into the deep sea. The underwater environment, characterized by high pressure, low temperature, complex sea conditions, and limited operating space, places higher demands on extraction technologies and equipment. Heavy oil resources constitute a significant proportion of deep-sea reserves, and their extraction typically requires a combination of thermal recovery and mechanical lifting processes.

[0003] In existing subsea heavy oil injection and production processes, a concentric twin-tube string structure is commonly used. During operation, the outer tubing string, connecting to the working barrel, must first be lowered to the subsea wellhead, followed by the inner tubing string, connecting to the inner pump barrel, and inserted into place. During the heating phase, the inner tubing string must be lifted by the drilling vessel or platform to remove the inner pump barrel from the working barrel, establishing an injection channel. After well shut-in and blowout are completed, the inner tubing string must be lowered back into the working barrel to switch to production mode. This technology requires two separate runs of tubing strings, significantly increasing operation time and development costs in high-cost marine areas. Furthermore, the frequent lowering and raising of the inner tubing string during injection-production transitions poses high operational risks and is severely dependent on sea condition and weather windows. Moreover, the configuration of two independent sets of tubing strings significantly increases the space occupied on the offshore platform deck, requiring strict control over pipe storage and the work area.

[0004] The purpose of this invention is to address the aforementioned shortcomings of existing technologies by providing a stationary tubing integrated injection-production concentric tube jet pump lifting device and method, particularly suitable for underwater environments. This technology aims to complete all operations with a single tubing run by optimizing the tubing structure, completely eliminating the need for tubing movement during injection-production conversion. This not only significantly saves platform operating space but also substantially shortens deep-sea operation time, reduces overall development costs and safety risks, providing reliable technical equipment for the economical and efficient development of deep-sea heavy oil resources.

[0005] Therefore, it is necessary to study a stationary tubing injection-production integrated concentric tube jet pump lifting device and method suitable for underwater environments, which eliminates the need for tubing movement during injection-production conversion in a single tubing operation, thereby significantly saving platform operating space, shortening deep-sea operation time, and reducing development costs and safety risks. Summary of the Invention

[0006] To address the aforementioned shortcomings in existing technologies, this invention provides an integrated concentric tube jet pump lifting device and method for injection and production using a stationary tubing string, thereby solving the problems of large platform space occupation, low operating efficiency, and high operating costs caused by the dual-tubing string structure in existing underwater heavy oil injection and production technologies.

[0007] To solve the above-mentioned technical problems, the present invention adopts the following technical solution: Compared with the prior art, the present invention has the following beneficial effects: 1. The present invention discloses a concentric tube jet pump lifting device and method for injection and production with a stationary tubing string. Through the single-pass tubing string design, it not only significantly reduces the occupation of deck space on the offshore platform, freeing up more working area for other key equipment, but also shortens the operation cycle, effectively reducing expenditures such as labor, ship and platform day fees, etc. At the same time, it simplifies the operation procedures, reduces manpower input, and effectively controls the comprehensive operating cost of deep-sea oil and gas development.

[0008] 2. The present invention discloses a fixed tubing integrated injection and production concentric tube jet pump lifting device and method. The fixed tubing structure simplifies the on-site operation procedure and reduces the complexity of operation. This not only reduces human error that may be caused by frequent operation, but also avoids the potential impact of tubing movement on the integrity of the wellbore, and improves the convenience and safety of operation.

[0009] 3. The present invention discloses a lifting device and method for an integrated concentric tube jet pump for injection and production with a stationary tubing. The safety valve can be opened when the safety valve fails by means of a forced opening locking device, which effectively improves the reliability of the equipment. Attached Figure Description

[0010] Figure 1 This is a schematic diagram of the structure of the present invention; Figure 2 This is a schematic diagram of the original well casing. Figure 3 This is a schematic diagram of the working pump assembly; Figure 4 This is a schematic diagram of the lock cylinder structure; Figure 5 This is a schematic diagram of the internal pump cylinder assembly; Figure 6 for Figure 5 Enlarged structural diagram at point A in the middle; Figure 7 This is a schematic diagram of the working pump assembly after it has been locked to the original well tubing. Figure 8 for Figure 7 Enlarged structural diagram at point B; Figure 9 This is a schematic diagram of the heat injection operation of the present invention; Figure 10 for Figure 9 Enlarged structural diagram at point C; Figure 11 This is a schematic diagram illustrating the forced opening and locking operation performed after the safety valve of the present invention fails. Figure 12This is a schematic diagram illustrating the production process following the forced unlocking and locking operation of this invention.

[0011] The reference numerals used in the attached figures are as follows: 1. Original well tubing string; 11. Outer tubing string; 12. Safety valve; 121. Safety valve spindle; 122. Valve plate; 2. Working pump assembly; 21. Sealing cylinder; 22. Tubing; 23. Outer cylinder; 231. Locking claw; 232. First groove; 234. First sealing part; 235. Second sealing part; 241. Spindle; 242. Locking tooth; 243. Second groove; 25. Locking cylinder; 251. Boss; 252. Locking ring; 253. Through slot; 254. Spring; 26. First pin; 27. Second pin; 3. Inner pump cylinder assembly; 31. Pump cylinder; 32. Upper plunger; 33. Steam injection valve; 331. Steam injection hole; 332. Pilot hole; 333. Fixed valve ball; 334. Fixed valve seat; 335. Flow hole; 34. Lower plunger; 4. First annular gap; 5. Second annular gap. Detailed Implementation

[0012] To enable those skilled in the art to better understand the present invention, the technical solution of the present invention will be further described below in conjunction with the accompanying drawings and embodiments.

[0013] In the description of this application, it should be noted that the directional terms such as "center", "lateral", "longitudinal", "length", "width", "thickness", "upper", "lower", "front", "rear", "left", "right", "vertical", "horizontal", "top", "bottom", "inner", "outer", "clockwise", and "counterclockwise" indicate the orientation and positional relationship based on the orientation or positional relationship shown in the accompanying drawings. They are only for the convenience of describing this application and simplifying the description, and do not indicate or imply that the device or element referred to must have a specific orientation, or be constructed and operated in a specific orientation. They should not be construed as limiting the specific protection scope of this application.

[0014] It should be noted that the terms "first," "second," etc., in the specification and claims of this application are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence.

[0015] Example 1

[0016] Please see Figures 1 to 12 As shown, a concentric jet pump lifting device for injection and production with a fixed tubing string is characterized by comprising: the original well tubing string 1, the working pump assembly 2, and the inner pump cylinder assembly 3.

[0017] The original well string 1 includes an outer tubing string 11 and a safety valve 12. The safety valve 12 is further equipped with a safety valve spindle 121 and a valve plate 122. The safety valve spindle 121 is slidably disposed within the safety valve 12 and is hinged to the bottom of the safety valve 12. The safety valve spindle 121 engages with the valve plate 122. It can be understood that when the safety valve spindle 121 is subjected to downward force, its lower end contacts the valve plate 122 and pushes the valve plate 122 downward. The working pump assembly 2 slides within the inner wall of the outer tubing string 11.

[0018] The working pump assembly 2 includes a sealing cylinder 21, an oil pipe 22, an outer cylinder 23, a forced opening locking device, a locking cylinder 25, a first pin 26, and a second pin 27. The sealing cylinder 21, the oil pipe 22, and the outer cylinder 23 are fixedly connected in sequence, and a first groove 232 is provided on the inner wall of the outer cylinder 23.

[0019] Specifically, the outer cylinder 23 is provided with a first sealing part 234 and a second sealing part 235. The first sealing part 234 is located at the lower part of the side wall of the outer cylinder 23, and the second sealing part 235 is located at the lower end opening of the outer cylinder 23. The first sealing part 234 and the second sealing part 235 cooperate with the inner wall of the outer tube column 11.

[0020] The forced-opening locking device includes a spindle 241, which is slidably disposed within the outer cylinder 23. A locking cylinder 25 is slidably disposed between the outer cylinder 23 and the spindle 241. The locking cylinder 25 is also provided with a boss 251, a locking ring 252, and a spring 254. The boss 251 is disposed on the upper end of the locking ring 252 and slides in contact with the inner wall of the first groove 232. The spring 254 is arranged around the first groove 232, and the boss 251 of the locking cylinder 25 is connected to the side wall of the first groove 232 via the spring 254. The locking ring 252 is fixedly disposed at the lower end of the locking cylinder 25 and engages with the lower end of the outer tube column 11. It should be noted that in this embodiment, the length of the locking cylinder 25 is such that when the second sealing part 235 is pressed against the outer tube column 11, the locking ring 252 engages precisely with the opening of the outer tube column 11.

[0021] This can be understood as follows: during the process of locking the working pump assembly 2 and the outer tube column 11 by pressing down the oil pipe, the locking cylinder 25 slides upward relative to the outer cylinder 23 when it encounters resistance, and the spring 254 is compressed. At the designed position where the working pump assembly 2 is lowered into the outer tube column 11, that is, after the second sealing part 235 is squeezed and engaged with the outer tube column 11, the spring 254 releases its elastic force and extends, pushing the locking cylinder 25 to slide downward until the locking ring 252 engages with the outer tube column 11.

[0022] Specifically, the locking ring 252 is provided with a through slot 253. This can be understood as the locking ring 252 bending towards the axis of the locking cylinder 25 when it is under force, as the locking cylinder 25 slides downward along the outer tubing 11. Correspondingly, a second groove 243 is provided on the side wall below the mandrel 241. When the locking ring 252 slides in contact with the inner wall of the original well tubing 1, the locking ring 252 bends inward into the second groove 243. When the locking ring 252 slides out of the outer tubing 11, the locking ring 252 bends away from the axis of the locking cylinder 25, and the locking ring 252 engages with the lower opening of the outer tubing 11.

[0023] The mandrel 241 and the outer cylinder 23 are connected by the first pin 26. It should be noted that before the first pin 26 is cut, the outer cylinder 23 and the mandrel 241 cannot slide relative to each other. After the first pin 26 is cut under the action of external force, the outer cylinder 23 and the mandrel 241 can slide relative to each other.

[0024] The inner wall is provided with a locking claw 231 extending in the axial direction. The side wall of the spindle 241 is provided with a locking tooth 242 extending in the direction opposite to the axial direction, and the locking claw 231 engages with the locking tooth 242. It should be noted that the engagement of the locking claw 231 and the locking tooth 242 is unidirectional. It can be understood that when the spindle 241 is subjected to force and slides downward along the outer cylinder 23, after the locking claw 231 moves below the locking tooth 242, the lower end face of the locking tooth 242 engages with the upper end face of the locking claw 231, restricting the spindle 241 from sliding upward.

[0025] The inner pump assembly 3 consists of a pump cylinder 31, an upper plunger 32, a steam injection valve 33, and a lower plunger 34, which are fixedly connected in sequence. The upper plunger 32 and the lower plunger 34 slide against the inner wall of the sealing cylinder 21. The lower plunger 34 engages with a forced-open locking device. The upper plunger 32 is connected to the sealing cylinder 21 via a second pin 27. It should be noted that before the second pin 27 is sheared, the upper plunger 32 and the sealing cylinder 21 cannot slide relative to each other. After the second pin 27 is sheared under external force, the upper plunger 32 and the sealing cylinder 21 can slide relative to each other.

[0026] It should be noted that after the working pump assembly 2 and the inner pump cylinder assembly 3 are lowered into the designed position in the outer tube column 11 through the oil pipe, and the oil pipe is pressed down to lock the working pump assembly 2 and the outer tube column 11, the oil pipe will be pulled up to cut the second pin 27 for subsequent operations.

[0027] This can be understood as follows: when safety valve 12 fails and valve plate 122 cannot open normally, the upper plunger 32 slides down along the sealing cylinder 21 by pressing down the oil pipe until the lower plunger 34 contacts the upper end of the spindle 241 and pushes the spindle 241 downward to shear the first pin 26. The spindle 241 moves downward and the lower end of the spindle 241 contacts the safety valve spindle 121 and pushes the safety valve spindle 121 downward together until the safety valve spindle 121 contacts the valve plate 122 and pushes the valve plate 122 to flip downward, thereby opening the safety valve 12. Then, the oil pipe is pulled up to the inner pump cylinder assembly 3 to reset and resume production.

[0028] It should be noted that during the downward sliding of the spindle 241, the locking claw 231 and the locking tooth 242 engage. After the oil pipe is pulled up to the inner pump cylinder assembly 3 to reset and resume production, the spindle 241 cannot slide upward, ensuring that the safety valve 12 always remains open.

[0029] Specifically, the steam injection valve 33 includes a steam injection hole 331, a pilot hole 332, a fixed valve ball 333, a fixed valve seat 334, and a flow passage 335. The fixed valve seat 334 and the fixed valve ball 333 are disposed in the steam injection valve 33, and the fixed valve ball 333 cooperates with the fixed valve seat 334. The steam injection valve 33 has a steam injection hole 331, a pilot hole 332, and a flow passage 335 on its side wall. The steam injection hole 331 and the pilot hole 332 are located above the fixed valve seat 334, and the flow passage 335 is located below the fixed valve seat 334.

[0030] Correspondingly, when the steam injection valve 33 is located in the sealing cylinder 21, a first annular gap 4 is provided between the steam injection valve 33 and the oil pipe 22.

[0031] Correspondingly, when the steam injection valve 33 is located in the oil pipe 22, a second annular gap 5 is provided between the steam injection valve 33 and the oil pipe 22.

[0032] The working principle of this invention is as follows: Before operation, the spindle 241 and the outer cylinder 23 are fixedly connected by the first pin 26. Then, the inner pump cylinder assembly 3 is installed in the working pump assembly 2. The inner pump cylinder assembly 3 and the working pump assembly 2 are fixedly connected by the second pin 27. The oil pipe is fixedly connected to the upper end of the pump cylinder 31.

[0033] The working pump assembly 2 and the inner pump cylinder assembly 3 are lowered into the designed position in the outer tube column 11 through the oil pipe. Then, the oil pipe is pressed down, and the oil pipe pushes the inner pump cylinder assembly 3 to slide downward relative to the working pump assembly 2. During this process, the locking cylinder 25 encounters resistance and slides upward relative to the outer cylinder 23. The spring 254 is compressed by force. At the same time, under the action of the through slot 253, the locking ring 252 bends towards the axis of the locking cylinder 25 into the second groove 243. At the designed position in the working pump assembly 2 in the outer tube column 11, that is, after the second sealing part 235 is squeezed and engaged with the outer tube column 11, the spring 254 releases its elastic force and extends, pushing the locking cylinder 25 to slide downward. After the locking ring 252 slides out of the outer tube column 11, the locking ring 252 bends away from the axis of the locking cylinder 25. The locking ring 252 and the lower opening of the outer tube column 11 are engaged, and the working pump assembly 2 and the outer tube column 11 are locked.

[0034] Then, pull up the tubing to cut the second pin 27, and at the same time slide the upper plunger 32 upward along the sealing cylinder 21 until the steam injection valve 33 is fully inserted into the sealing cylinder 21. At this time, the equipment enters the well completion state. After pressure testing the outer tubing string 11 and the tubing respectively, steam is introduced into the inner pump cylinder assembly 3 through the tubing for heat injection operation.

[0035] In the heat injection mode, during the initial stage of heat injection, the steam injection hole 331 of the steam injection valve 33 is blocked by the sealing cylinder 21, and the steam injected into the fixed valve ball 333 is pressurized into the fixed valve seat 334. The gas enters the safety valve 12 through the channel formed by the oil pipe, pump cylinder 31, upper plunger 32, pilot hole 332, first annular gap 4, flow hole 335, lower plunger 34, oil pipe 22, and mandrel 241, and pushes open the safety valve plate 122 to inject into the formation.

[0036] In the later stage of heat injection, as the temperature of the steam-injected outer tubing 11 and the tubing rises, they elongate. Since the tubing does not have a heat insulation layer, its elongation is greater than that of the outer tubing 11. As a result, the tubing, together with the upper plunger 32, slides down along the sealing cylinder 21 until the steam injection valve 33 is fully inserted into the tubing 22. Steam enters the steam injection valve 33 through the tubing, pump cylinder 31, and upper plunger 32. Then, it enters the second annular gap 5 through the steam injection hole 331 and the pilot hole 332. Finally, it enters the safety valve 12 through the channel formed by the flow hole 335, the lower plunger 34, the tubing 22, and the mandrel 241, and pushes open the safety valve plate 122 to inject into the formation, thus achieving automatic switching from the heat injection channel without moving the tubing.

[0037] After the heating process is completed, a well-shutting operation is performed, and after the well-shutting operation is completed, the production mode is switched to blowout production mode.

[0038] In the blowout production mode, heavy oil enters the oil pipe through the channel formed by safety valve 12, mandrel 241, oil pipe 22, lower plunger 34, steam injection valve 33, upper plunger 32 and pump barrel 31.

[0039] When the safety valve fails to open normally, the upper plunger 32 slides downward along the sealing cylinder 21 by pressing down the oil pipe until the lower plunger 34 contacts the upper end of the spindle 241 and pushes the spindle 241 downward to shear the first pin 26. The lower end of the spindle 241 then contacts the safety valve spindle 121 and pushes it downward together until it contacts the valve plate 122 and pushes it to flip downward, thus opening the safety valve 12. Afterward, the oil pipe is pulled up to reset the inner pump cylinder assembly 3. During the downward sliding of the spindle 241, the locking claw 231 and locking tooth 242 engage. After the oil pipe is pulled up to reset the inner pump cylinder assembly 3 and production resumes, the spindle 241 cannot slide upward, ensuring that the safety valve 12 always remains open.

[0040] After the blowout production mode ends, a fixed valve and a jet pump production core are inserted into the tubing, so that the jet pump production core enters the predetermined position in the pump barrel 31. Then, power fluid is injected through the surface plunger pump to switch to the well production mode. This part is existing technology and will not be described in detail here.

[0041] Example 2

[0042] This embodiment describes a jet pump lifting method using the integrated concentric tubing jet pump lifting device for injection and production described in Embodiment 1, which includes the following steps: S1. The core shaft 241 and the outer cylinder 23 are fixedly connected by the first pin 26, the inner pump cylinder assembly 3 is installed in the working pump assembly 2, and the inner pump cylinder assembly 3 and the working pump assembly 2 are fixedly connected by the second pin 27. S2. Connect the upper end of the pump cylinder 31 to the oil pipe, and lower the working pump assembly 2 and the inner pump cylinder assembly 3 into the designed position in the outer tube column 11 through the oil pipe, and press down the oil pipe to lock the working pump assembly 2 and the outer tube column 11. S3. Pull up the oil pipe to cut off the second pin 27. The inner pump cylinder assembly 3 slides upward along the outer cylinder 23 until the steam injection valve 33 is completely slid into the sealing cylinder 21. S4. Perform pressure tests on the outer tubing string 11 and the tubing separately; S5. Steam is injected into the oil pipe through the heating equipment. When the safety valve 12 cannot be opened normally, the oil pipe is pressed down to cut the first pin 26 and the safety valve 12 is opened by the forced opening locking device. S6. After the heating is completed, the well is shut-off operation is carried out. After the well shut-off operation is completed, the production mode is switched to self-flowing production mode. S7. After the self-flowing production mode ends, a fixed valve and a jet pump production core are inserted into the tubing, so that the jet pump production core enters the predetermined position in the pump barrel 31, and then the power fluid is injected through the ground plunger pump to switch to the oil well production mode.

[0043] The above descriptions are merely embodiments of the present invention. Commonly known structures and characteristics of the solutions are not described in detail here. Those skilled in the art are aware of all common technical knowledge in the field prior to the application date or priority date, are aware of all existing technologies in that field, and have the ability to apply conventional experimental methods prior to that date. Those skilled in the art can, under the guidance of this application, improve and implement this solution in combination with their own capabilities. Some typical known structures or methods should not be obstacles for those skilled in the art to implement this application. It should be noted that those skilled in the art can make several modifications and improvements without departing from the structure of the present invention. These should also be considered within the scope of protection of the present invention, and will not affect the effectiveness of the implementation of the present invention or the practicality of the patent.

Claims

1. A lifting device for an integrated concentric tube jet pump for injection and production using a stationary tubing string, characterized in that, include: Original well tubing (1), working pump assembly (2) and inner pump cylinder assembly (3); The original well string (1) includes an outer string (11) and a safety valve (12). The safety valve (12) is also provided with a safety valve spindle (121) and a valve plate (122). The safety valve spindle (121) is slidably disposed in the safety valve (12) and is hinged to the bottom of the safety valve (12). The working pump assembly (2) is slidably engaged with the inner wall of the outer string (11). The safety valve spindle (121) is engaged with the valve plate (122). The working pump assembly (2) includes a sealing cylinder (21), an oil pipe (22), an outer cylinder (23), a forced opening locking device, a locking cylinder (25), a first pin (26), and a second pin (27). The sealing cylinder (21), the oil pipe (22), and the outer cylinder (23) are fixedly connected in sequence. The inner wall of the outer cylinder (23) is provided with a first groove (232). The forced opening locking device includes a spindle (241), which is slidably disposed in the outer cylinder (23). The locking cylinder (25) is slidably disposed between the outer cylinder (23) and the spindle (241). The locking cylinder (25) is also provided with a boss (251), a locking ring (252) and a spring (254). The boss (251) is disposed on the upper end of the locking ring (252). 1) The spring (254) is slidably engaged with the inner wall of the first groove (232), and the boss (251) of the lock cylinder (25) is connected to the side wall of the first groove (232) through the spring (254). The lock ring (252) is fixedly disposed at the lower end of the lock cylinder (25), and the lock ring (252) is engaged with the lower end of the outer tube column (11). The spindle (241) and the outer cylinder (23) are connected through the first pin (26). The inner pump cylinder assembly (3) consists of a pump cylinder (31), an upper plunger (32), a steam injection valve (33), and a lower plunger (34) that are fixedly connected in sequence. The upper plunger (32) and the lower plunger (34) slide in cooperation with the inner wall of the sealing cylinder (21). The lower plunger (34) cooperates with the forced opening locking device. The upper plunger (32) is connected to the sealing cylinder (21) through the second pin (27).

2. The integrated concentric tube jet pump lifting device for injection and production using a stationary tubing as described in claim 1, characterized in that: The inner wall of the outer cylinder (23) is provided with a locking claw (231) extending in the axial direction.

3. The integrated concentric tube jet pump lifting device for injection and production using a stationary tubing as described in claim 2, characterized in that: The side wall of the mandrel (241) is provided with locking teeth (242) extending in the direction away from the axis, and the locking claw (231) engages with the locking teeth (242).

4. The integrated concentric tube jet pump lifting device for injection and production using a stationary tubing as described in claim 1, characterized in that: The outer cylinder (23) is provided with a first sealing part (234) and a second sealing part (235). The first sealing part (234) is located at the lower part of the side wall of the outer cylinder (23), and the second sealing part (235) is located at the lower end opening of the outer cylinder (23). The first sealing part (234) and the second sealing part (235) cooperate with the inner wall of the outer tube column (11).

5. The integrated concentric tube jet pump lifting device for injection and production using a stationary tubing as described in claim 1, characterized in that: The locking ring (252) is provided with a through slot (253).

6. The integrated concentric tube jet pump lifting device for injection and production using a stationary tubing as described in claim 5, characterized in that: A second groove (243) is provided on the side wall below the mandrel (241). When the locking ring (252) slides in conjunction with the inner wall of the original well string (1), the locking ring (252) bends inward into the second groove (243).

7. The integrated concentric tube jet pump lifting device for injection and production using a stationary tubing as described in claim 1, characterized in that: The steam injection valve (33) includes a steam injection hole (331), a pilot hole (332), a fixed valve ball (333), a fixed valve seat (334), and a flow passage (335). The fixed valve seat (334) is disposed in the steam injection valve (33), and the fixed valve ball (333) is disposed in the steam injection valve (33). The fixed valve ball (333) cooperates with the fixed valve seat (334). The steam injection valve (33) has a steam injection hole (331), a pilot hole (332), and a flow passage (335) on its side wall. The steam injection hole (331) and the pilot hole (332) are located above the fixed valve seat (334), and the flow passage (335) is located below the fixed valve seat (334).

8. The integrated concentric tube jet pump lifting device for injection and production using a stationary tubing as described in claim 1, characterized in that: When the steam injection valve (33) is located in the sealing cylinder (21), a first annular gap (4) is provided between the steam injection valve (33) and the oil pipe (22).

9. The integrated concentric tube jet pump lifting device for injection and production using a stationary tubing as described in claim 8, characterized in that: When the steam injection valve (33) is located in the oil pipe (22), a second annular gap (5) is provided between the steam injection valve (33) and the oil pipe (22).

10. A method for lifting a jet pump, characterized in that: Using the integrated concentric tubing jet pump lifting device for injection and production using any one of claims 1-9, the method comprises the following steps: S1. The core shaft (241) and the outer cylinder (23) are fixedly connected by the first pin (26), the inner pump cylinder assembly (3) is installed in the working pump assembly (2), and the inner pump cylinder assembly (3) and the working pump assembly (2) are fixedly connected by the second pin (27). S2. Connect the upper end of the pump barrel (31) to the oil pipe, and lower the working pump assembly (2) and the inner pump barrel assembly (3) into the designed position in the outer pipe column (11) through the oil pipe, and press down the oil pipe to lock the working pump assembly (2) and the outer pipe column (11). S3, pull up the oil pipe to cut off the second pin (27), and the inner pump cylinder assembly (3) slides upward along the outer cylinder (23) until the steam injection valve (33) slides completely into the sealing cylinder (21); S4. Perform pressure tests on the outer tubing (11) and tubing separately; S5. Steam is injected into the oil pipe through the heating equipment. When the safety valve (12) fails, the first pin (26) is cut off by the pressure oil pipe and the safety valve (12) is opened by the forced opening locking device. S6. After the heating is completed, the well is shut-off operation is carried out. After the well shut-off operation is completed, the production mode is switched to self-flowing production mode. S7. After the self-flowing production mode ends, a fixed valve and a jet pump production core are put into the tubing, so that the jet pump production core enters the predetermined position in the pump barrel (31), and then the power fluid is injected through the ground plunger pump to switch to the oil well production mode.

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