Horizontal well simultaneous injection and production pipe column

Abstract

This invention relates to a horizontal well tubing string for simultaneous injection and production in a single well, comprising a pump, an upper bridge packer, a production bridge working tube, a lower bridge packer, a hydraulic packer, and a soluble bottom plug. The upper bridge packer has independent first central channels and first bridge channels, and is externally fitted with a first rubber sleeve structure. The production bridge working tube has independent second central channels and second bridge channels, and is also provided with a lateral opening connecting the second central channels and the outside of the production bridge working tube. A temporary pipe for sealing the lateral opening is connected to the lateral opening via a temporary shear pin. The lower bridge packer has independent third central channels and third bridge channels, and is externally fitted with a second rubber sleeve structure. This tubing string enables water injection in the middle section and oil production at both ends of a horizontal well, with the injected water and produced fluid flow channels not interfering with each other.

Description

Technical Field

[0001] This invention relates to the field of oilfield water injection development technology, and in particular to a horizontal well simultaneous injection and production tubing string. Background Technology

[0002] Currently, the development of horizontal wells in unconventional reservoirs faces challenges such as insignificant formation energy replenishment, difficulty in establishing an effective displacement system, significant degradation, and the risk of water breakthrough due to fractures in some wells. Simultaneous injection and production in a single well, a novel technology for both oil production and water injection, is an effective means of establishing lateral displacement in the wellbore. Existing patents cannot achieve simultaneous injection and production replenishment in a horizontal well, with water injection in the middle section and oil production at both ends. Existing technology discloses an intelligent layered water injection and production tubing string for horizontal wells (invention patent publication number CN109751020A), which can only achieve water injection at the root of the horizontal well and fingertip oil production. Water injection is done through the casing, and oil production is done through the tubing, resulting in only one injection and one production cycle in the horizontal well. The process is simple, lacks relevant key tools, and the tubing string has low utilization of remaining lateral oil, with no effective solution after water breakthrough. Existing technology also discloses a horizontal well induction and outflow intelligent segmented water injection process string (utility model patent with authorization number CN205936555U), which can only realize segmented well shut-in and outflow of horizontal wells. In the production process of this string, water is injected first to replenish energy, and then the well is shut in and shut-in. The crude oil is replaced by seepage and then the well is opened for production. However, this process string has problems such as the effect of the production gradually deteriorates after multiple rounds of production and the difficulty in determining the reasonable well shut-in time.

[0003] Therefore, based on years of experience and practice in related industries, the inventor proposes a method for simultaneous injection and production tubing in horizontal wells to overcome the shortcomings of existing technologies. Summary of the Invention

[0004] The purpose of this invention is to provide a horizontal well with a simultaneous injection and production tubing string, which can realize water injection in the middle section and oil production at both ends of the horizontal well, and the flow channels of the injected water and the produced fluid do not interfere with each other.

[0005] The objective of this invention is achieved as follows: a horizontal well with simultaneous injection and production tubing, comprising a pump, an upper bridge packer, a production bridge working tube, a lower bridge packer, a hydraulic packer, and a soluble bottom plug connected in sequence; the upper bridge packer has an independent first central channel and a first bridge channel, and an external first rubber sleeve structure capable of setting when pressurized within the first central channel; the production bridge working tube has an independent second central channel and a second bridge channel, and a lateral opening connecting the second central channel and the outside of the production bridge working tube is provided on the lateral opening. The opening is connected to a temporary tube that can seal the lateral opening via temporary shear pins; the lower bridge packer has an independent third central channel and a third bridge channel, and the lower bridge packer has a second rubber sleeve structure that can be set when pressurized in the third central channel; wherein, the shearing pressure of the temporary shear pins is greater than the setting pressure of the first rubber sleeve structure, the second rubber sleeve structure and the hydraulic packer; the two ends of the first bridge channel can be connected to the outside of the upper bridge packer and the upper end of the second bridge channel respectively, the lower end of the second bridge channel can be connected to the upper end of the third bridge channel, and the lower end of the third bridge channel can be connected to the outside of the lower bridge packer.

[0006] In a preferred embodiment of the present invention, the upper bridge packer includes a first diversion tube, a first outer tube sleeved and fixed outside the first diversion tube, a first rubber sleeve structure sleeved on the first outer tube, and a first piston; the inner cavity of the first diversion tube forms a first central channel, and a gap is left between the first outer tube and the first diversion tube to form a first bridge-type channel with the upper end closed and the lower end open; a lateral water injection hole is provided on the first outer tube and above the first rubber sleeve structure, and the lateral water injection hole communicates with the first bridge channel and the outside of the upper bridge packer; the outer wall of the first outer tube has a first limiting portion, the first... The upper end of the rubber sleeve structure can abut against the first limiting part, and the upper end of the first piston can abut against the lower end of the first rubber sleeve structure. The first piston is connected to the first outer tube through the first setting shear pin. A first sealing cavity is formed between the first piston and the first outer tube. A first liquid inlet is provided on the first diverter pipe. The first liquid inlet is connected to the first central channel and the first sealing cavity and is isolated from the first bridge channel. A first anti-reverse ring is also provided between the first piston and the first outer tube and between the first sealing cavity and the first setting shear pin. The first piston can move axially upward in one direction and is connected to the first anti-reverse ring.

[0007] In a preferred embodiment of the present invention, a first stop portion is provided on the outer wall of the first outer tube and below the first sealing cavity, and a first unsealing retaining ring is provided between the first outer tube and the first piston. The two ends of the first anti-reverse ring abut against the first stop portion and the first unsealing retaining ring respectively, and the first unsealing retaining ring is connected to the first outer tube through a first unsealing shear pin.

[0008] In a preferred embodiment of the present invention, the first outer tube includes, in order from top to bottom, a first upper connector, a first sealing sleeve, a first connecting sleeve, a first setting sleeve, and a first lower connector. The inner wall of the middle portion of the first upper connector is threadedly sealed to the outer wall of the upper end of the first diverter tube. The inner wall of the lower end of the first upper connector is threadedly sealed to the outer wall of the upper end of the first sealing sleeve. The outer wall of the lower end of the first sealing sleeve is threadedly connected to the inner wall of the upper end of the first connecting sleeve. The outer wall of the lower end of the first connecting sleeve is threadedly connected to the inner wall of the upper end of the first setting sleeve. The outer wall of the lower end of the first setting sleeve is threadedly connected to the inner wall of the upper end of the first lower connector. The inner diameters of the first sealing sleeve, the first connecting sleeve, the first setting sleeve, and the first lower connector are similar. Similarly, the inner walls of the four components are spaced apart from the outer wall of the first diversion pipe, forming a first bridge-type channel; a first limiting ring is threadedly connected to the outside of the first sealing sleeve, and a gap is left between the first limiting ring and the lower end of the first upper connector. The lateral water injection hole is opened on the first sealing sleeve and is set with a corresponding gap. The lower end of the first limiting ring forms the first limiting part; the first anti-reverse ring and the first unsealing ring are both sleeved on the first seated sleeve. The first unsealing ring is connected to the first seated sleeve through the first unsealing shear pin; a first shearing ring is threadedly sleeved at the lower part of the first seated sleeve and between the first unsealing ring and the first lower connector. The lower end of the first piston is connected to the first shearing ring through the first seated shear pin.

[0009] In a preferred embodiment of the present invention, the first piston includes a first upper piston tube, a first lower piston tube, and a first locking sleeve arranged sequentially. A first upper protruding ring protrudes inward from the inner wall of the upper end of the first upper piston tube, and the inner wall of the first upper protruding ring can seal against the outer wall of the first sealing sleeve. The lower inner wall of the first upper piston tube is threadedly connected to the upper outer wall of the first lower piston tube, and a first lower protruding ring protrudes inward from the inner wall of the upper end of the first lower piston tube, and the inner wall of the first lower protruding ring can seal against the outer wall of the first connecting sleeve. A first upper ring cavity is formed between the middle inner wall of the first upper piston tube and the outer wall of the first outer tube. An annular first upper flange protrudes outward from the outer wall of the upper end of the first connecting sleeve, the first upper flange being located within the first upper ring cavity, and the outer wall of the first upper flange sealing against the inner wall of the first upper piston tube. The upper end face of the first upper flange and the lower end face of the first upper ring form a first upper sealing cavity; the upper outer wall of the first seat sleeve has an annular first lower flange protruding outward, which can seal against the inner wall of the first lower piston tube, and the upper end face of the first lower flange and the lower end face of the first lower ring form a first lower sealing cavity, the first upper sealing cavity and the first lower sealing cavity constitute the first sealing cavity; the lower outer wall of the first lower piston tube is internally threaded to the upper end of the first locking sleeve, the lower end face of the first lower flange constitutes a first stop part, and the lower end of the first locking sleeve is connected to the first shearing retaining ring through the first seat shear pin; the middle inner wall of the first locking sleeve and the outer wall of the first seat sleeve form a first lower ring cavity, and the first anti-reverse ring and the first release retaining ring are both located in the first lower ring cavity.

[0010] In a preferred embodiment of the present invention, a plurality of first upper through holes are circumferentially spaced at positions corresponding to the first upper sealing cavity on the first sealing sleeve, and a plurality of first upper arc-shaped blocks are circumferentially spaced at positions on the outer wall of the first diverter tube. Each first upper arc-shaped block is provided with a first upper radial hole, which can connect the first central channel and the corresponding first upper through hole. A plurality of first lower through holes are circumferentially spaced at positions corresponding to the first lower sealing cavity on the first connecting sleeve, and a plurality of first lower arc-shaped blocks are circumferentially spaced at positions on the outer wall of the first diverter tube. Each first lower arc-shaped block is provided with a first lower radial hole, which can connect the first central channel and the corresponding first lower through hole. The first upper radial hole and the first lower radial hole constitute a first liquid inlet.

[0011] In a preferred embodiment of the present invention, the oil production bridge working tube includes a second diversion pipe and a second outer pipe spaced outside the second diversion pipe. The inner cavity of the second diversion pipe forms a second central channel, and the gap between the second outer pipe and the second diversion pipe forms a second bridge channel with both ends open. A plurality of second through holes are circumferentially spaced on the second outer pipe, and a plurality of second arc-shaped blocks are circumferentially spaced on the outer wall of the second diversion pipe. Each second arc-shaped block has a second radial hole. The second radial hole can connect the second central channel and the corresponding second through hole, and the second radial hole and the corresponding second through hole form a lateral opening. A temporary pipe is connected to the second outer pipe through a temporary shear pin and can seal and block each second through hole. The lower end of the first outer pipe and the upper end of the second outer pipe are connected through a first outer oil pipe, and the lower end of the first diversion pipe and the upper end of the second diversion pipe are connected through a first inner oil pipe. The first oil pipe annulus formed between the first outer oil pipe and the first inner oil pipe can communicate with both the first bridge channel and the second bridge channel.

[0012] In a preferred embodiment of the present invention, the second diversion pipe includes a first inner tube sealing cylinder and a diversion inner pipe. The lower inner wall of the first inner tube sealing cylinder is threadedly sealed to the upper outer wall of the diversion inner pipe. The first inner oil pipe can be sealed and inserted into the first inner tube sealing cylinder and abut against the upper end surface of the diversion inner pipe. The second arc-shaped block is formed on the diversion inner pipe.

[0013] In a preferred embodiment of the present invention, the second outer tube includes a second upper connector, a diversion outer tube, and a second lower connector arranged sequentially. The lower inner wall of the second upper connector is threadedly sealed to the upper outer wall of the diversion outer tube. The diversion outer tube is welded and fixed to each of the second arc-shaped blocks. The lower outer wall of the diversion outer tube is threadedly sealed to the upper inner wall of the second lower connector. The inner walls of the second upper connector, the diversion outer tube, and the second lower connector are spaced apart from the outer wall of the diversion inner tube to form a second bridge-type channel. A second through hole is opened on the diversion outer tube. A temporary tube is sleeved on the outside of the diversion outer tube, and its upper end is sealed to the outer wall of the second upper connector and connected to the second upper connector through a temporary shear pin. Its lower end is sealed to the diversion outer tube and located below the second through hole.

[0014] In a preferred embodiment of the present invention, the lower bridge packer includes a third diversion pipe, a third outer pipe sleeved and fixed outside the third diversion pipe, a second rubber sleeve structure and a second piston sleeved on the third outer pipe; the inner cavity of the third diversion pipe forms a third central channel, and a gap is left between the third outer pipe and the third diversion pipe to form a third bridge channel with an open upper end and a closed lower end; a lateral water outlet is provided on the third outer pipe near the lower end of the third bridge channel, and the lateral water outlet communicates with the third bridge channel; the outer wall of the third outer pipe has a second limiting part, the upper end of the second rubber sleeve structure can abut against the second limiting part, the upper end of the second piston can abut against the lower end of the second rubber sleeve structure, and the second piston is connected to the second sealing shear pin. The third outer tube is connected; a second sealing cavity is formed between the second piston and the third outer tube; a second liquid inlet is provided on the third branch pipe; the second liquid inlet is connected to the third central channel and the second sealing cavity and isolated from the third bridge channel; a second anti-reverse ring is also provided between the second piston and the third outer tube and between the second sealing cavity and the second setting shear pin; the second piston can move axially upward in one direction and is connected to the second anti-reverse ring; the lower end of the second outer tube is connected to the upper end of the third outer tube through a second outer oil pipe; the lower end of the second branch pipe is connected to the upper end of the third branch pipe through a second inner oil pipe; the second oil pipe annulus formed between the second outer oil pipe and the second inner oil pipe can be connected to both the second bridge channel and the third bridge channel.

[0015] In a preferred embodiment of the present invention, a second stop portion is provided on the outer wall of the third outer tube and below the second sealing cavity, and a second unsealing retaining ring is provided between the third outer tube and the second piston. The two ends of the second anti-reverse ring respectively abut against the second stop portion and the second unsealing retaining ring, and the second unsealing retaining ring is connected to the third outer tube through a second unsealing shear pin.

[0016] In a preferred embodiment of the present invention, the upper outer wall of the third diversion pipe is threadedly sealed to the lower inner wall of the second inner tube sealing cylinder, and the second inner oil pipe can be sealed and inserted into the second inner tube sealing cylinder and abut against the upper end face of the third diversion pipe.

[0017] In a preferred embodiment of the present invention, the third outer pipe includes, in order from top to bottom, a third upper connector, a second sealing sleeve, a second connecting sleeve, a second setting sleeve, a water injection screen pipe, and a third lower connector. The upper inner wall of the third upper connector is threadedly connected to the second outer oil pipe, and the lower inner wall of the third upper connector is threadedly sealed to the upper outer wall of the second sealing sleeve. The lower outer wall of the second sealing sleeve is threadedly connected to the upper inner wall of the second connecting sleeve, the lower outer wall of the second connecting sleeve is threadedly connected to the upper inner wall of the second setting sleeve, the lower outer wall of the second setting sleeve is threadedly connected to the upper inner wall of the water injection screen pipe, the lower inner wall of the water injection screen pipe is threadedly connected to the upper outer wall of the third lower connector, and the upper inner wall of the third lower connector is threaded to the lower outer wall of the third diversion pipe. The wall is threaded and sealed; the inner wall of the third upper connector, the second sealing sleeve, the second connecting sleeve, the second setting sleeve, and the water injection screen pipe are spaced apart from the outer wall of the third diversion pipe, forming a third bridge-type channel; a second limiting ring is also threadedly connected to the lower end of the third upper connector outside the second sealing sleeve, the lower end of the second limiting ring forms the second limiting part, and the screen holes of the water injection screen pipe form a lateral water outlet; the second anti-reverse ring and the second unsealing ring are both sleeved on the second setting sleeve, and the second unsealing ring is connected to the second setting sleeve through the second unsealing shear pin; a second shearing ring is threadedly sleeved at the lower part of the second setting sleeve and between the second unsealing ring and the water injection screen pipe, and the lower end of the second piston is connected to the second shearing ring through the second setting pin.

[0018] In a preferred embodiment of the present invention, the second piston includes a second upper piston tube, a second lower piston tube, and a second locking sleeve arranged sequentially. A second upper protruding ring protrudes inward from the inner wall of the upper end of the second upper piston tube, and the inner wall of the second upper protruding ring can seal against the outer wall of the second sealing sleeve. The lower inner wall of the second upper piston tube is threadedly connected to the upper outer wall of the second lower piston tube, and a second lower protruding ring protrudes inward from the inner wall of the upper end of the second lower piston tube, and the inner wall of the second lower protruding ring can seal against the outer wall of the second connecting sleeve. A second upper ring cavity is formed between the middle inner wall of the second upper piston tube and the outer wall of the third outer tube. An annular second upper flange protrudes outward from the outer wall of the upper end of the second connecting sleeve, the second upper flange being located within the second upper ring cavity, and the outer wall of the second upper flange sealing against the inner wall of the second upper piston tube. A second upper sealing cavity is formed between the upper end face of the second upper flange and the lower end face of the second upper ring; an annular second lower flange protrudes outward from the upper outer wall of the second seat sleeve, and the second lower flange can make sealing contact with the inner wall of the second lower piston tube, and a second lower sealing cavity is formed between the upper end face of the second lower flange and the lower end face of the second lower ring, the second upper sealing cavity and the second lower sealing cavity constitute the second sealing cavity; the lower outer wall of the second lower piston tube is internally threaded to the upper end of the second locking sleeve, the lower end face of the second lower flange constitutes the second stop part, and the lower end of the second locking sleeve is connected to the second shearing retaining ring through the second seat shear pin; a second lower ring cavity is formed between the middle inner wall of the second locking sleeve and the outer wall of the second seat sleeve, and the second anti-reverse ring and the second release retaining ring are both located in the second lower ring cavity.

[0019] In a preferred embodiment of the present invention, a plurality of third upper through holes are circumferentially spaced at positions corresponding to the second upper sealing cavity on the second sealing sleeve, and a plurality of third upper arc-shaped blocks are circumferentially spaced at positions on the outer wall of the third flow tube, each of which has a third upper radial hole that can connect the third central channel and the corresponding third upper through hole; a plurality of third lower through holes are circumferentially spaced at positions corresponding to the second lower sealing cavity on the second connecting sleeve, and a plurality of third lower arc-shaped blocks are circumferentially spaced at positions on the outer wall of the third flow tube, each of which has a third lower radial hole that can connect the third central channel and the corresponding third lower through hole; the third upper radial hole and the third lower radial hole constitute the second liquid inlet hole.

[0020] In a preferred embodiment of the present invention, the portion of the first outer tube located above the first rubber sleeve structure and the portion of the third outer tube located above the second rubber sleeve structure are both made of non-metallic drillable material.

[0021] In a preferred embodiment of the present invention, a first safety release connector is connected above the upper bridge packer, a second safety release connector is connected above the lower bridge packer, and a third safety release connector is connected above the hydraulic packer.

[0022] In a preferred embodiment of the present invention, an oil production screen and a plug are sequentially connected below the soluble bottom plug.

[0023] In a preferred embodiment of the present invention, a tube hanger is also connected between the oil pump and the upper bridge packer, and the lower end of the oil pump can be sealed and inserted into the tube hanger.

[0024] In a preferred embodiment of the present invention, a first soluble centralizer is connected above or below the upper bridge packer, a second soluble centralizer is connected above or below the lower bridge packer, and a third soluble centralizer is connected below the hydraulic packer.

[0025] As described above, in the tubing string of this application, the upper bridge packer, the oil production bridge working tube, and the lower bridge packer all have independent central channels and bridge channels, enabling injected water and produced fluid to complete injection and production through their respective independent flow channels. Through the cooperation of its components, the entire tubing string effectively solves the problem of interference between injected water and produced fluid during simultaneous injection and production at both ends in horizontal wells. It achieves simultaneous injection and production at both ends of a horizontal well, further broadening the applicability of the simultaneous injection and production technology for horizontal wells, and is simple in design and easy to operate. Attached Figure Description

[0026] The following figures are intended only to illustrate and explain the present invention and do not limit the scope of the invention. Wherein:

[0027] Figure 1 : A schematic diagram of the structure of a horizontal well with simultaneous injection and production tubing provided by the present invention.

[0028] Figure 2 : A cross-sectional view of the upper bridge packer provided by the present invention.

[0029] Figure 3 :for Figure 2 Enlarged view of part of the structure.

[0030] Figure 4 : A cross-sectional view of the oil production bridge-type working cylinder provided by the present invention.

[0031] Figure 5 : A cross-sectional view of the lower bridge packer provided by the present invention.

[0032] Figure 6 :for Figure 5 Enlarged view of part of the structure.

[0033] Explanation of icon numbers:

[0034] 100. Oil pump;

[0035] 200. Intubation cannula hanger;

[0036] 300. Top-bridge packer;

[0037] 301. First Central Passage; 302. First Bridge-Type Passage;

[0038] 303, First branch pipe; 3031, First upper arc-shaped block; 30311, First upper radial hole; 3032, First lower arc-shaped block; 30321, First lower radial hole;

[0039] 304, First outer tube; 3041, First upper connector; 3042, First sealing sleeve; 30421, First limiting retaining ring; 30422, Lateral water injection hole; 30423, First upper through hole; 3043, First connecting sleeve; 30431, First upper flange; 30432, First lower through hole; 3044, First setting sleeve; 30441, First anti-reverse ring; 30442, First unsealing retaining ring; 30443, First unsealing shear pin; 30444, First shearing retaining ring; 30445, First lower flange; 3045, First lower connector;

[0040] 305. First rubber sleeve structure;

[0041] 306. First piston; 3061. First upper piston tube; 30611. First upper convex ring; 30612. First upper ring cavity; 30613. First upper sealing cavity; 3062. First lower piston tube; 30621. First lower convex ring; 30622. First lower sealing cavity; 3063. First locking sleeve; 30631. First lower ring cavity; 3064. First setting shear pin;

[0042] 400. Oil production bridge-type working cylinder;

[0043] 401. Second central passage; 402. Second bridge-type passage; 403. Lateral opening; 404. Temporary pipe; 4041. Temporary shear studs;

[0044] 405, Second diversion pipe; 4051, First inner tube sealing cylinder; 4052, Diversion inner pipe; 40521, Second arc-shaped block; 405211, Second radial hole;

[0045] 406. Second outer tube; 4061. Second upper connector; 4062. Diverter outer tube; 40621. Second through hole; 4063. Second lower connector;

[0046] 500. Lower bridge packer;

[0047] 501. Third Central Passage; 502. Third Bridge-Type Passage;

[0048] 503, Third Diverter Pipe; 5031, Third Upper Arc Block; 50311, Third Upper Radial Hole; 5032, Third Lower Arc Block; 50321, Third Lower Radial Hole; 5033, Second Inner Tube Sealing Cylinder;

[0049] 504, Third outer tube; 5041, Third upper connector; 5042, Second sealing sleeve; 50421, Second limiting ring; 50422, Third upper through hole; 5043, Second connecting sleeve; 50431, Second upper flange; 50432, Third lower through hole; 5044, Second setting sleeve; 50441, Second anti-reverse ring; 50442, Second unsealing ring; 50443, Second unsealing shear pin; 50444, Second shearing ring; 50445, Second lower flange; 5045, Water injection screen pipe; 5046, Third lower connector;

[0050] 505. Second rubber sleeve structure;

[0051] 506. Second piston; 5061. Second upper piston tube; 50611. Second upper convex ring; 50612. Second upper ring cavity; 50613. Second upper sealing cavity; 5062. Second lower piston tube; 50621. Second lower convex ring; 50622. Second lower sealing cavity; 5063. Second locking sleeve; 50631. Second lower ring cavity; 5064. Second setting shear pin;

[0052] 600. Hydraulic packer;

[0053] 700, Soluble bottom plug; 701, Oil production screen pipe; 702, Threaded plug; 703, Ball seat;

[0054] 801. First soluble stabilizer; 802. Second soluble stabilizer; 803. Third soluble stabilizer;

[0055] 901. First safety release connector; 902. Second safety release connector; 903. Third safety release connector. Detailed Implementation

[0056] To provide a clearer understanding of the technical features, objectives, and effects of the present invention, specific embodiments of the present invention will now be described with reference to the accompanying drawings.

[0057] like Figures 1 to 6As shown, this application provides a horizontal well with simultaneous injection and production tubing, including a pumping unit 100, an upper bridge packer 300, a production bridge working tube 400, a lower bridge packer 500, a hydraulic packer 600, and a soluble bottom plug 700 connected in sequence. The upper bridge packer 300 has an independent first central channel 301 and a first bridge channel 302, and the upper bridge packer 300 has a first rubber sleeve structure 305 that can be set when pressurized in the first central channel 301. The production bridge working tube 400 has an independent second central channel 301 and a first bridge channel 302. The oil production bridge working barrel 400 is provided with a second central channel 401 and a second bridge channel 402. A lateral opening 403 is also provided on the second central channel 401 and the outside of the oil production bridge working barrel 400. A temporary pipe 404 that can seal and block the lateral opening 403 is connected at the lateral opening 403 by a temporary shear pin 4041. The lower bridge packer 500 has an independent third central channel 501 and a third bridge channel 502 inside. The lower bridge packer 500 has a second rubber sleeve structure 505 that can be set when pressure is applied in the third central channel 501.

[0058] Among them, the shearing pressure of the temporary shearing nail 4041 is greater than the setting pressure of the first rubber sleeve structure 305, the second rubber sleeve structure 505 and the hydraulic packer 600; the two ends of the first bridge channel 302 can be connected to the outside of the upper bridge packer 300 and the upper end of the second bridge channel 402 respectively, the lower end of the second bridge channel 402 can be connected to the upper end of the third bridge channel 502, and the lower end of the third bridge channel 502 can be connected to the outside of the lower bridge packer 500.

[0059] Specifically, the soluble bottom plug 700 can automatically dissolve after a certain period of use. The setting pressures of the upper bridge packer 300, the lower bridge packer 500, and the hydraulic packer 600 are basically similar. The hydraulic packer 600 can be any type of hydraulic packer. For example, the Y341 packer is used in this embodiment. The Y453 cannulated packer can also be used as needed. After the entire tubing string is lowered to the designated position, the soluble bottom plug 700 seals the bottom of the tubing string, and pressure is applied to the tubing. The pressurized liquid flows through the first central channel 301, the second central channel 401, and the third central channel 501. Under liquid pressure, the first rubber sleeve structure 305, the second rubber sleeve structure 505, and the hydraulic packer 600 are all set against the inner wall of the casing to separate the upper production section, the intermediate water injection section, and the lower production section. Specifically, the area between the first rubber sleeve structure 305 and the second rubber sleeve structure 505 faces the upper production section, the area between the second rubber sleeve structure 505 and the hydraulic packer 600 faces the intermediate water injection section, and the area below the hydraulic packer 600 faces the lower production section. Pressure is then applied continuously until the pressure reaches a preset value, at which point the temporary shear pin 4041 cuts the pressure, and the second central channel 401 connects to the annulus through the lateral opening 403. After a certain period of time, the soluble bottom plug 700 will automatically dissolve, allowing the bottom of the entire tubing string to connect with the annulus of the oil sleeve.

[0060] During simultaneous injection and production, the injected water enters from the annulus, passes through the upper end of the first bridge channel 302 of the upper bridge packer 300, then through the second bridge channel 402 of the production bridge working barrel 400 and the third central channel 501 of the lower bridge packer 500, and then enters the annulus from the lower end of the third central channel 501, finally entering the intermediate water injection section formation to achieve intermediate water injection. Simultaneously, under the action of the pumping unit 100, the oil from the upper production section formation enters the second central channel 401 through the lateral opening 403 of the production bridge working barrel 400, while the oil from the lower production section formation enters the tubing string through the bottom of the tubing string, then flows upwards into the third central channel 501 and the second central channel 401, continuing upwards together with the oil from the upper production section formation into the first central channel 301, and finally is extracted from the wellhead, achieving two-end oil production.

[0061] Therefore, in the tubing string of this application, the upper bridge packer 300, the oil production bridge working tube 400, and the lower bridge packer 500 all have independent central channels and bridge channels, which can realize the injection and production of water and produced fluid through their respective independent flow channels. Through the cooperation of various components, the entire tubing string can effectively solve the problem of mutual interference between injected water and produced fluid during the simultaneous injection and production replenishment process in horizontal wells, which exists in the middle injection and production at both ends. It realizes the simultaneous injection and production replenishment of water in the middle section and oil production at both ends of the horizontal well, further broadening the applicability of the simultaneous injection and production replenishment process in horizontal wells, and is simple in design and easy to operate.

[0062] Specifically, refer to Figure 2 and Figure 3 The upper bridge packer 300 includes a first diversion pipe 303, a first outer pipe 304 sleeved and fixed outside the first diversion pipe 303, and a first rubber sleeve structure 305 and a first piston 306 sleeved on the first outer pipe 304. The inner cavity of the first diversion pipe 303 forms a first central channel 301. There is a gap between the first outer pipe 304 and the first diversion pipe 303, which forms a first bridge channel 302 with the upper end closed and the lower end open. A lateral water injection hole 30422 is opened on the first outer pipe 304 and above the first rubber sleeve structure 305. The lateral water injection hole 30422 communicates with the first bridge channel 302 and the outside of the upper bridge packer 300.

[0063] The outer wall of the first outer tube 304 has a first limiting part. The upper end of the first rubber sleeve structure 305 can abut against the first limiting part. The upper end of the first piston 306 can abut against the lower end of the first rubber sleeve structure 305. The first piston 306 is connected to the first outer tube 304 through the first setting shear pin 3064. A first sealing cavity is formed between the first piston 306 and the first outer tube 304. A first liquid inlet is provided on the first diversion pipe 303. The first liquid inlet communicates with the first central channel 301 and the first sealing cavity and is isolated from the first bridge channel 302. A first anti-reverse ring 30441 is also provided between the first piston 306 and the first outer tube 304 and between the first sealing cavity and the first setting shear pin 3064. The first piston 306 can move axially upward in one direction and is connected to the first anti-reverse ring 30441.

[0064] During pressure setting, the pressurizing fluid enters the first central channel 301 and then flows into the first sealing cavity through the first inlet hole. When the pressure reaches a certain value, the first setting shear pin 3064 shears off, the first piston 306 moves upward, and pushes the first rubber sleeve structure 305 upward to achieve setting. During simultaneous injection and production, the injected water enters from the annulus of the oil sleeve and then flows into the first bridge channel 302 through the side injection hole 30422, and then continues to descend through the open bottom end of the first bridge channel 302. The first anti-reverse ring 30441 effectively ensures that the first rubber sleeve structure 305 will not retract after moving upward and setting, preventing unsealing.

[0065] To facilitate the subsequent unsealing of the upper bridge packer 300, a first stop is provided on the outer wall of the first outer tube 304 and below the first sealing cavity. A first unsealing retaining ring 30442 is also provided between the first outer tube 304 and the first piston 306. The two ends of the first anti-reverse ring 30441 abut against the first stop and the first unsealing retaining ring 30442 respectively. The first unsealing retaining ring 30442 is connected to the first outer tube 304 through the first unsealing shear pin 30443.

[0066] When unsealing is required, lift the tubing column and pull the first outer tube 304 and the first diversion tube 303 upward together. When the upward pull reaches a certain value, the first unsealing shear pin 30443 breaks, and the first rubber sleeve structure 305 is unsealed.

[0067] Generally, to facilitate the processing and installation of the first outer tube 304, the first outer tube 304 includes a first upper connector 3041, a first sealing sleeve 3042, a first connecting sleeve 3043, a first seated sleeve 3044, and a first lower connector 3045 connected sequentially from top to bottom. The middle inner wall of the first upper connector 3041 is threadedly sealed to the upper outer wall of the first diverter 303. The lower inner wall of the first upper connector 3041 is threadedly sealed to the upper outer wall of the first sealing sleeve 3042. The lower outer wall of the first sealing sleeve 3042 is threadedly connected to the upper inner wall of the first connecting sleeve 3043. The lower outer wall of the first connecting sleeve 3043 is threadedly connected to the upper inner wall of the first seated sleeve 3044. The lower outer wall of the first seated sleeve 3044 is threadedly connected to the upper inner wall of the first lower connector 3045.

[0068] The inner diameters of the first sealing sleeve 3042, the first connecting sleeve 3043, the first seat sleeve 3044, and the first lower connector 3045 are the same, and the inner walls of the four are spaced apart from the outer wall of the first diversion pipe 303, forming a first bridge-type channel 302; a first limiting ring 30421 is also threaded onto the outside of the first sealing sleeve 3042, and a gap is left between the first limiting ring 30421 and the lower end of the first upper connector 3041. A lateral water injection hole 30422 is opened on the first sealing sleeve 3042 and is set with a corresponding gap. The lower end of 0421 forms the first limiting part; the first anti-reverse ring 30441 and the first unsealing retaining ring 30442 are both sleeved on the first seated sleeve 3044, and the first unsealing retaining ring 30442 is connected to the first seated sleeve 3044 through the first unsealing shear pin 30443; the first shearing retaining ring 30444 is threadedly sleeved at the lower part of the first seated sleeve 3044 and between the first unsealing retaining ring 30442 and the first lower connector 3045, and the lower end of the first piston 306 is connected to the first shearing retaining ring 30444 through the first seated shear pin 3064.

[0069] To facilitate the first piston 306 pushing the first rubber sleeve structure 305 to achieve setting and sealing during pressurization, refer to Figure 2 and Figure 3The first piston 306 includes a first upper piston tube 3061, a first lower piston tube 3062, and a first locking sleeve 3063 arranged sequentially. The upper inner wall of the first upper piston tube 3061 is provided with a first upper protruding ring 30611 protruding inward, and the inner wall of the first upper protruding ring 30611 can seal and contact the outer wall of the first sealing sleeve 3042. The lower inner wall of the first upper piston tube 3061 is threadedly connected to the upper outer wall of the first lower piston tube 3062, and the upper inner wall of the first lower piston tube 3062 is provided with a first lower protruding ring 30621 protruding inward, and the inner wall of the first lower protruding ring 30621 can seal and contact the outer wall of the first connecting sleeve 3043.

[0070] A first upper annular cavity 30612 is formed between the inner wall of the middle portion of the first upper piston tube 3061 and the outer wall of the first outer tube 304. An annular first upper flange 30431 protrudes outward from the upper outer wall of the first connecting sleeve 3043. The first upper flange 30431 is located within the first upper annular cavity 30612, and its outer wall can make sealing contact with the inner wall of the first upper piston tube 3061. The upper end face of the first upper flange 30431 is in contact with the lower end face of the first upper annular ring 30611. A first upper sealing cavity 30613 is formed between the end faces; the upper outer wall of the first seat sleeve 3044 is provided with an annular first lower flange 30445, which can seal and contact the inner wall of the first lower piston tube 3062, and a first lower sealing cavity 30622 is formed between the upper end face of the first lower flange 30445 and the lower end face of the first lower convex ring 30621. The first upper sealing cavity 30613 and the first lower sealing cavity 30622 constitute the first sealing cavity.

[0071] The lower outer wall of the first lower piston tube 3062 is threadedly connected to the upper inner wall of the first locking sleeve 3063. The lower end face of the first lower flange 30445 forms the first stop portion. The lower end of the first locking sleeve 3063 is connected to the first shearing retaining ring 30444 through the first setting shear pin 3064. A first lower annular cavity 30631 is formed between the middle inner wall of the first locking sleeve 3063 and the outer wall of the first setting sleeve 3044. The first anti-reverse ring 30441 and the first unsealing retaining ring 30442 are both located in the first lower annular cavity 30631.

[0072] To facilitate the connection between the first inlet hole and the first central channel 301, and the isolation from the first bridge channel 302, multiple first upper through holes 30423 are circumferentially spaced on the first sealing sleeve 3042 at positions corresponding to the first upper sealing cavity 30613. Multiple first upper arc-shaped blocks 3031 are circumferentially spaced on the outer wall of the first diverter pipe 303. Each first upper arc-shaped block 3031 has a first upper radial hole 30311, which connects the first central channel 301 and the corresponding first upper through hole 30423. 0423; Multiple first lower through holes 30432 are circumferentially spaced at positions corresponding to the first lower sealing cavity 30622 on the first connecting sleeve 3043, and multiple first lower arc-shaped blocks 3032 are circumferentially spaced on the outer wall of the first diversion pipe 303. Each first lower arc-shaped block 3032 is provided with a first lower radial hole 30321. The first lower radial hole 30321 can connect the first central channel 301 and the corresponding first lower through hole 30432; the first upper radial hole 30311 and the first lower radial hole 30321 constitute the first liquid inlet hole.

[0073] In a feasible embodiment, a first upper axial channel passing through both ends of the first upper arc-shaped block 3031 and a first lower axial channel passing through both ends of the first lower arc-shaped block 3032 can also be provided. Both the first upper axial channel and the first lower axial channel are connected to the first bridge channel 302. The first upper axial channel is isolated from the first upper radial hole 30311 and the first lower axial channel is isolated from the first lower radial hole 30321.

[0074] Furthermore, referring to Figure 4 The oil production bridge-type working cylinder 400 includes a second diversion pipe 405 and a second outer pipe 406 spaced outside the second diversion pipe 405. The inner cavity of the second diversion pipe 405 forms a second central channel 401, and the gap between the second outer pipe 406 and the second diversion pipe 405 forms a second bridge-type channel 402 that is open at both ends. A plurality of second through holes 40621 are circumferentially spaced on the second outer pipe 406, and a plurality of second arc-shaped blocks 40521 are circumferentially spaced on the outer wall of the second diversion pipe 405. Each second arc-shaped block 40521 has a second radial hole 405211. The second radial hole 405211 can connect the second central channel 401 and the corresponding second through hole 40621. The second radial hole 405211 and the corresponding second through hole 40621 form a lateral opening 403. A temporary pipe 404 is connected to the second outer pipe 406 through a temporary shear pin 4041 and can seal and block each second through hole 40621.

[0075] The lower end of the first outer pipe 304 is connected to the upper end of the second outer pipe 406 through a first outer oil pipe, and the lower end of the first shunt pipe 303 is connected to the upper end of the second shunt pipe 405 through a first inner oil pipe. The first oil pipe annulus formed between the first outer oil pipe and the first inner oil pipe can be connected to both the first bridge channel 302 and the second bridge channel 402.

[0076] For ease of processing and installation, the second diversion pipe 405 includes a first inner tube sealing cylinder 4051 and a diversion inner pipe 4052. The lower inner wall of the first inner tube sealing cylinder 4051 is threadedly sealed to the upper outer wall of the diversion inner pipe 4052. The first inner oil pipe can be sealed and inserted (fixed) inside the first inner tube sealing cylinder 4051 and abut against the upper end face of the diversion inner pipe 4052. The second arc-shaped block 40521 is formed on the diversion inner pipe 4052.

[0077] The second outer tube 406 includes a second upper connector 4061, a diversion outer tube 4062, and a second lower connector 4063 arranged sequentially. The lower inner wall of the second upper connector 4061 is threadedly sealed to the upper outer wall of the diversion outer tube 4062. The diversion outer tube 4062 is welded and fixed to each of the second arc-shaped blocks 40521. The lower outer wall of the diversion outer tube 4062 is threadedly sealed to the upper inner wall of the second lower connector 4063. The second upper connector 4061, the diversion outer tube 4062, and the second lower connector 4063 are sequentially arranged sequentially. A gap is left between the inner wall of the connector 4063 and the outer wall of the diversion inner tube 4052, forming a second bridge-type channel 402. The second through hole 40621 is opened on the diversion outer tube 4062. The temporary tube 404 is sleeved on the outside of the diversion outer tube 4062, and its upper end is in sealed contact with the outer wall of the second upper connector 4061 and connected to the second upper connector 4061 through a temporary shear pin 4041. Its lower end is in sealed contact with the diversion outer tube 4062 and located below the second through hole 40621.

[0078] Furthermore, referring to Figure 5 and Figure 6 The lower bridge packer 500 includes a third diversion pipe 503, a third outer pipe 504 sleeved and fixed outside the third diversion pipe 503, and a second rubber sleeve structure 505 and a second piston 506 sleeved on the third outer pipe 504. The inner cavity of the third diversion pipe 503 forms a third central channel 501. There is a gap between the third outer pipe 504 and the third diversion pipe 503, which forms a third bridge channel 502 with an open upper end and a closed lower end. A lateral water outlet is provided on the third outer pipe 504 and near the lower end of the third bridge channel 502. The lateral water outlet communicates with the third bridge channel 502.

[0079] The outer wall of the third outer tube 504 has a second limiting part. The upper end of the second rubber sleeve structure 505 can abut against the second limiting part. The upper end of the second piston 506 can abut against the lower end of the second rubber sleeve structure 505. The second piston 506 is connected to the third outer tube 504 through the second setting shear pin 5064. A second sealing cavity is formed between the second piston 506 and the third outer tube 504. A second liquid inlet is provided on the third three-way flow tube 503. The second liquid inlet communicates with the third central channel 501 and the second sealing cavity and is isolated from the third bridge channel 502. A second anti-reverse ring 50441 is also provided between the second piston 506 and the third outer tube 504 and between the second sealing cavity and the second setting shear pin 5064. The second piston 506 can move axially upward in one direction and is connected to the second anti-reverse ring 50441.

[0080] The lower end of the second outer pipe 406 is connected to the upper end of the third outer pipe 504 through a second outer oil pipe, and the lower end of the second branch pipe 405 is connected to the upper end of the third branch pipe 503 through a second inner oil pipe. The second oil pipe annulus formed between the second outer oil pipe and the second inner oil pipe can be connected to both the second bridge channel 402 and the third bridge channel 502.

[0081] To facilitate the subsequent release of the lower bridge packer 500, a second stop is provided on the outer wall of the third outer tube 504 and below the second sealing cavity. A second release retaining ring 50442 is also provided between the third outer tube 504 and the second piston 506. The two ends of the second anti-reverse ring 50441 abut against the second stop and the second release retaining ring 50442 respectively. The second release retaining ring 50442 is connected to the third outer tube 504 through the second release shear pin 50443.

[0082] When unsealing is required, lift the tubing column and pull the third outer tube 504 and the third diversion tube 503 upward together. When the upward pull reaches a certain value, the second unsealing shear pin 50443 disconnects, and the second rubber sleeve structure 505 is unsealed.

[0083] To facilitate the connection between the lower bridge packer 500 and the oil production bridge working cylinder 400, the upper outer wall of the third diversion pipe 503 is threadedly sealed to the lower inner wall of the second inner tube sealing cylinder 5033. The second inner oil pipe can be sealed and inserted (fixed) inside the second inner tube sealing cylinder 5033 and abut against the upper end face of the third diversion pipe 503.

[0084] To facilitate the processing and installation of the third outer tube 504, the third outer tube 504 generally includes, from top to bottom, a third upper connector 5041, a second sealing sleeve 5042, a second connecting sleeve 5043, a second setting sleeve 5044, a water injection screen pipe 5045, and a third lower connector 5046. The upper inner wall of the third upper connector 5041 is threadedly connected to the second outer oil pipe, and the lower inner wall of the third upper connector 5041 is threadedly sealed to the upper outer wall of the second sealing sleeve 5042. The lower outer wall of 5042 is threadedly connected to the upper inner wall of the second connecting sleeve 5043. The lower outer wall of the second connecting sleeve 5043 is threadedly connected to the upper inner wall of the second seat sleeve 5044. The lower outer wall of the second seat sleeve 5044 is threadedly connected to the upper inner wall of the water injection screen pipe 5045. The lower inner wall of the water injection screen pipe 5045 is threadedly connected to the upper outer wall of the third lower connector 5046. The upper inner wall of the third lower connector 5046 is threadedly and sealed to the lower outer wall of the third diversion pipe 503.

[0085] The inner walls of the third upper connector 5041, the second sealing sleeve 5042, the second connecting sleeve 5043, the second setting sleeve 5044, and the water injection screen pipe 5045 are spaced apart from the outer wall of the third diversion pipe 503, forming a third bridge-type channel 502. A second limiting ring 50421 is threadedly connected to the lower end of the third upper connector 5041, close to the outer side of the second sealing sleeve 5042. The lower end of the second limiting ring 50421 forms a second limiting part. The screen holes of the water injection screen pipe 5045 form a lateral outlet. Water hole; the second anti-reverse ring 50441 and the second unsealing retaining ring 50442 are both sleeved on the second seat sleeve 5044. The second unsealing retaining ring 50442 is connected to the second seat sleeve 5044 through the second unsealing shear pin 50443. The second shear retaining ring 50444 is threadedly sleeved at the lower part of the second seat sleeve 5044 and between the second unsealing retaining ring 50442 and the water injection screen pipe 5045. The lower end of the second piston 506 is connected to the second shear retaining ring 50444 through the second seat pin.

[0086] To facilitate the second piston 506 pushing the second rubber sleeve structure 505 to achieve setting and sealing during pressurization, refer to... Figure 5 and Figure 6 The second piston 506 includes a second upper piston tube 5061, a second lower piston tube 5062, and a second locking sleeve 5063 arranged sequentially. The upper inner wall of the second upper piston tube 5061 is provided with a second upper protruding ring 50611 protruding inward, and the inner wall of the second upper protruding ring 50611 can seal and contact the outer wall of the second sealing sleeve 5042. The lower inner wall of the second upper piston tube 5061 is threadedly connected to the upper outer wall of the second lower piston tube 5062, and the upper inner wall of the second lower piston tube 5062 is provided with a second lower protruding ring 50621 protruding inward, and the inner wall of the second lower protruding ring 50621 can seal and contact the outer wall of the second connecting sleeve 5043.

[0087] A second upper annular cavity 50612 is formed between the inner wall of the middle portion of the second upper piston tube 5061 and the outer wall of the third outer tube 504. An annular second upper flange 50431 protrudes outward from the upper outer wall of the second connecting sleeve 5043. The second upper flange 50431 is located within the second upper annular cavity 50612, and its outer wall can seal against the inner wall of the second upper piston tube 5061. The upper end face of the second upper flange 50431 is in contact with the lower end face of the second upper annular cavity 50611. A second upper sealing cavity 50613 is formed between the end faces; the upper outer wall of the second seat sleeve 5044 is provided with an annular second lower flange 50445, which can seal and contact the inner wall of the second lower piston tube 5062, and a second lower sealing cavity 50622 is formed between the upper end face of the second lower flange 50445 and the lower end face of the second lower convex ring 50621. The second upper sealing cavity 50613 and the second lower sealing cavity 50622 constitute the second sealing cavity.

[0088] The lower outer wall of the second lower piston tube 5062 is threadedly connected to the upper inner wall of the second locking sleeve 5063. The lower end face of the second lower flange 50445 forms the second stop portion. The lower end of the second locking sleeve 5063 is connected to the second shearing retaining ring 50444 through the second setting shear pin 5064. A second lower annular cavity 50631 is formed between the middle inner wall of the second locking sleeve 5063 and the outer wall of the second setting sleeve 5044. The second anti-reverse ring 50441 and the second unsealing retaining ring 50442 are both located in the second lower annular cavity 50631.

[0089] To facilitate the connection between the second inlet hole and the third central channel 501, and the isolation from the third bridge channel 502, multiple third upper through holes 50422 are circumferentially spaced on the second sealing sleeve 5042 at positions corresponding to the second upper sealing cavity 50613. Multiple third upper arc-shaped blocks 5031 are circumferentially spaced on the outer wall of the third flow tube 503. Each third upper arc-shaped block 5031 has a third upper radial hole 50311, which connects the third central channel 501 and the corresponding third upper through hole 50422. 0422; On the second connecting sleeve 5043, a plurality of third lower through holes 50432 are circumferentially spaced at the position corresponding to the second lower sealing cavity 50622. On the outer wall of the third flow tube 503, a plurality of third lower arc-shaped blocks 5032 are circumferentially spaced. Each third lower arc-shaped block 5032 is provided with a third lower radial hole 50321. The third lower radial hole 50321 can connect the third central channel 501 and the corresponding third lower through hole 50432. The third upper radial hole 50311 and the third lower radial hole 50321 constitute the second liquid inlet hole.

[0090] In a feasible embodiment, a second upper axial channel passing through both ends of the third upper arc-shaped block 5031 and a second lower axial channel passing through both ends of the third lower arc-shaped block 5032 can also be provided. Both the second upper axial channel and the second lower axial channel are connected to the third bridge channel 502. The second upper axial channel is isolated from the third upper radial hole 50311, and the second lower axial channel is isolated from the third lower radial hole 50321.

[0091] Furthermore, the portions of the first outer tube 304 located above the first rubber sleeve structure 305 (specifically, the first upper connector 3041 and the first limiting ring 30421) and the portions of the third outer tube 504 located above the second rubber sleeve structure 505 (specifically, the third upper connector 5041 and the second limiting ring 50421) are both made of non-metallic drillable materials, such as some resin fibers. In this embodiment, the first upper connector 3041 and the first limiting ring 30421 are both made of 35CrMo, the second upper connector 4061 is made of 42CrMo, and the second limiting ring 50421 is made of carbon composite material.

[0092] When the tubing cannot be successfully unsealed, drilling out the corresponding non-metallic drillable material can help unseal the tubing.

[0093] Reference Figure 1 Generally, a first safety release connector 901 is connected above the upper bridge packer 300, a second safety release connector 902 is connected above the lower bridge packer 500, and a third safety release connector 903 is connected above the hydraulic packer 600.

[0094] The specific structure of the safety release connector is the existing structure. When a release is required or normal release is not possible, a certain upward force can be applied to the tubing to disengage it from the safety release connector. By using the aforementioned non-metallic drillable materials in conjunction with the various safety release connectors, the tubing can be released and lifted when it cannot be easily retrieved.

[0095] During normal well tripping, the drop tool is lowered and connected to the hydraulic packer 600. If it can be lifted successfully, the hydraulic packer 600 and each bridge packer are successively released. If the drop tool fails to release the packer, a non-metallic drillable material can be drilled. The rubber sleeve loses support and retracts inward, releasing the packer. After release, well washing and other operations can be performed. After the operations are completed, the tubing string is lowered into the well according to the downhole procedure.

[0096] In order to filter the extracted oil, refer to Figure 1 Below the soluble bottom plug 700, an oil production screen pipe 701 and a threaded plug 702 are sequentially connected. In an optional embodiment, a ball seat 703 can also be connected above the soluble bottom plug 700, and the ball is thrown before pressure setting, and then pressure setting is performed.

[0097] To facilitate the suspension of the tubing string and to make it easier to maintain the oil pump 100 without lifting the entire tubing string, a tube hanger 200 is connected between the oil pump 100 and the upper bridge packer 300. The lower end of the oil pump 100 can be sealed and inserted (fixed) in the tube hanger 200.

[0098] In order to stabilize the tubing string during its run-in, a first soluble centralizer 801 is connected above or below the upper bridge packer 300, a second soluble centralizer 802 is connected above or below the lower bridge packer 500, and a third soluble centralizer 803 is connected below the hydraulic packer 600.

[0099] It should be noted that the upward and downward positions and similar expressions mentioned in the text are for illustrative purposes only and do not represent the only possible implementation. It is understood that a horizontal well includes a vertically connected section and a horizontal section. When the tubing string is lowered using a workover rig, the sucker pump 100 and the tubing hanger 200 are located within the vertical section of the horizontal well, while the first safety joint and subsequent components are lowered into the horizontal section. The threaded sealing connection between the two components specifically refers to the components being fixed by a threaded connection, with a sealing ring sandwiched between the two components to ensure a tight seal.

[0100] In more detail, the construction steps for the entire tubular string are as follows:

[0101] Step 1: Assemble the plug 702, production screen 701, soluble bottom plug 700, third soluble centralizer 803, hydraulic packer 600, third safety release connector 903, second soluble centralizer 802, lower bridge packer 500, and second outer tubing into a tool string at the wellhead and run it down the well. Connect the second safety release connector 902 in series with the second outer tubing. When the lower bridge packer 500 reaches the wellhead, the upper end of the second outer tubing sits at the wellhead position. Run the second inner tubing in, and after the lower end of the second inner tubing passes through the inner cavity of the second safety release connector 902, seal it and insert it into the sealing cylinder 5033 of the second inner tube of the lower bridge packer 500, abutting against the upper end face of the third flow pipe 503. After the second inner tubing is in place, lift it a certain distance so that the upper end of the second inner tubing protrudes from the wellhead. At this time, the second inner tubing can move up and down and rotate.

[0102] Next, connect the upper end of the second inner oil pipe to the lower end of the outer wall of the inner branch pipe 4052 of the oil production bridge working cylinder 400. Then, move the oil production bridge working cylinder 400 downward so that the lower end thread of the second lower connector 4063 aligns with the thread of the second outer oil pipe. While screwing the second lower connector 4063, the second inner oil pipe also moves downward until the lower end of the second inner oil pipe abuts against the upper end face of the third branch pipe 503. At this point, the threaded connection between the second lower connector 4063 and the second outer oil pipe is completed.

[0103] The first outer tubing is threaded to the upper end of the second upper connector 4061. The first soluble centralizer 801 is connected in series in the first outer tubing. The tubing string is continued to be lowered, and the upper end of the first outer tubing is positioned at the wellhead. Then, the first inner tubing is lowered and sealed inside the first inner tube sealing cylinder 4051 of the oil production bridge working cylinder 400 and abuts against the upper end face of the diversion inner tube 4052. After the first inner tubing is lowered into place, it is lifted a certain distance so that the upper end of the first inner tubing is exposed at the wellhead. At this time, the first inner tubing can move up and down and rotate.

[0104] Then, the upper end of the first inner oil pipe is threadedly connected to the lower outer wall of the first shunt pipe 303 of the upper bridge packer 300. The upper bridge packer 300 is then moved downwards until the lower thread of the first lower connector 3045 aligns with the thread of the first outer oil pipe. While tightening the first lower connector 3045, the first inner oil pipe also moves downwards until its lower end abuts against the upper surface of the shunt inner pipe 4052. At this point, the threaded connection between the first lower connector 3045 and the first outer oil pipe is complete. Afterwards, the first safety release connector 901 is connected to the upper end of the first upper connector 3041 of the upper bridge packer 300.

[0105] Continue lowering the tool string and connecting the tubing. Once it reaches the designated position, connect the tubing hanger 200 and connect it to the upper tubing via multiple upper shear pins above the tubing hanger 200.

[0106] Step 2: After the tubing string is lowered, the tubing is pressure-set and the upper tubing is disconnected from the insertion hanger 200.

[0107] Step 3: Finally, connect the oil pump 100 above the tubing hanger 200, lower the sucker rod, inject water into the annulus, and start oil production through the tubing.

[0108] in, Figure 1 In the diagram, M indicates the direction of the injected water flow, and N indicates the direction of the extracted oil flow.

[0109] In step two above, the soluble bottom plug 700 seals the bottom of the tubing. When the ground-connected pump truck pressurizes the tubing, the pressurizing fluid sequentially enters the first central channel 301, the first inner oil pipe, the second central channel 401, the second inner oil pipe, the third central channel 501, and the inner cavity of the hydraulic packer 600. The pressurizing fluid entering the first central channel 301 flows into the first upper sealing cavity 30613 through the first upper radial hole 30311 and the first upper through hole 30423, and enters the first lower sealing cavity 30622 through the first lower radial hole 30321 and the first lower through hole 30432. The pressurizing fluid simultaneously pushes the first upper piston tube 3061 and the first lower piston tube 3062 upwards. When the pressure reaches a certain value, the first setting shear pin 3064 shears off the first upper piston tube. 3061. The first lower piston tube 3062 and the first locking sleeve 3063 move upward together and push the first rubber sleeve structure 305 upward to achieve setting. The pressurizing fluid entering the third central channel 501 flows into the second upper sealing cavity 50613 through the third upper radial hole 50311 and the third upper through hole 50422, and enters the second lower sealing cavity 50622 through the third lower radial hole 50321 and the third lower through hole 50432. The pressurizing fluid pushes the second upper piston tube 5061 and the second lower piston tube 5062 upward at the same time. When the pressure reaches a certain value, the second setting shear pin 5064 cuts off. The second upper piston tube 5061, the second lower piston tube 5062 and the second locking sleeve 5063 move upward together and push the second rubber sleeve structure 505 upward to achieve setting.

[0110] The setting pressures of the aforementioned upper-bridge packer 300, lower-bridge packer 500, and hydraulic packer 600 are similar, and also similar to the setting pressure of the aforementioned tubing hanger 200. After tubing pressurization, the tubing hanger 200, upper-bridge packer 300, lower-bridge packer 500, and hydraulic packer 600 all achieve setting. The tubing hanger 200 can effectively support and suspend the entire tubing string, and each soluble centralizer plays a role in straightening the tubing string during insertion and pressurization for setting, ensuring uniform sealing. The outer wall of each of the aforementioned anti-reverse rings is provided with multiple locking teeth, and the inner wall of the corresponding locking sleeve is provided with multiple reverse teeth. These reverse teeth can engage with the locking teeth. When the locking sleeve moves upward, the multiple reverse teeth of the locking sleeve will engage with the multiple locking teeth on the anti-reverse ring. These reverse teeth can move upward along the axis of the multiple locking teeth, but will not move backward. That is, the locking sleeve can move upward along the anti-reverse ring, but cannot move downward along the anti-reverse ring, so as to effectively prevent the rubber sleeve structure from being unsealed.

[0111] Afterwards, the pressure continues to increase to a preset value, at which point the temporary shear pin 4041 cuts off, and the second central channel 401 can connect with the annulus through the lateral opening 403. Additionally, after the pressure reaches a certain value, the upper shear pin between the insertion pipe hanger 200 and the upper oil pipe disconnects, separating the two.

[0112] After a certain period of time, the soluble bottom plug 700 will automatically dissolve, allowing the bottom of the entire tubing string to connect with the annulus of the casing. Each soluble centralizer will also automatically dissolve, specifically the part of the soluble centralizer that extends outside the tubing string and rests against the casing will automatically dissolve, in order to facilitate the later removal of the tubing string.

[0113] In step three above: the external pipe of the oil pump 100 is sealed and fixed in the pipe hanger 200, and then the sucker rod is lowered. During simultaneous injection and production, the injected water enters from the annulus and then enters the first bridge channel 302 through the lateral water injection hole 30422. Then it continues to descend through the open end of the bottom of the first bridge channel 302, enters the first tubing annulus, and then sequentially enters the second bridge channel 402, the second tubing annulus and the third bridge channel 502. Then it enters the annulus through the screen holes on the water injection screen pipe 5045, and finally enters the intermediate water injection section formation to achieve intermediate water injection.

[0114] Meanwhile, under the action of the oil pump 100, the oil from the upper production section enters the second central channel 401 through the lateral opening 403 of the oil production bridge working cylinder 400, and the oil from the lower production section enters the tubing string through the side wall hole of the oil production screen pipe 701 at the bottom of the tubing string. It then enters the third central channel 501, the second inner tubing, and the second central channel 401 in sequence. Together with the oil from the upper production section, it continues to enter the first inner tubing and the first central channel 301, and is finally pumped out of the wellhead, achieving oil production at both ends.

[0115] Furthermore, the development of quasi-natural energy in horizontal wells is subject to rapid decline and the risk of water flooding is high during water injection development. However, the horizontal well injection-production energy replenishment process in this embodiment can solve the problem of insufficient development energy in horizontal wells in low-permeability reservoirs, significantly reduce the risk of water flooding in horizontal wells, and is an effective means of establishing lateral displacement of the horizontal wellbore.

[0116] There are currently no application examples of the simultaneous injection and production process in horizontal wells with injection at both ends. In this embodiment, the tubing string utilizes key tools such as the 400mm production bridge working tube and bridge packer to effectively solve the problem of interference between injected water and produced fluid during simultaneous injection and production in horizontal wells. It also significantly improves the utilization of remaining oil in horizontal wells, especially in the waist region, maintaining formation pressure levels and substantially increasing the average formation pressure compared to waterflooding. This process features cost reduction, efficiency improvement, increased production, and environmental friendliness, significantly improving the utilization of remaining oil in horizontal wells, especially in the waist region. Horizontal well refueling can be achieved with a single tubing string run, resulting in high operational efficiency and lower construction costs compared to traditional horizontal well injection-production refueling processes. Compared to traditional refueling technologies, it can establish a long-term effective lateral displacement system and significantly improve the utilization of remaining oil in horizontal wells, especially in the waist region. Compared to traditional refueling processes, it can effectively shorten construction time by more than 15 days.

[0117] Furthermore, downhole intelligent injection and production devices are typically installed at the outlet of the production section and the inlet of the injection section, with the lower connector of the downhole intelligent injection and production device connected to the tubing. The downhole intelligent injection and production device is designed with an injection-production connector, which includes a water nozzle. During the injection and production process, the electrically controlled pressure-balancing water nozzle, under the action of a motor, controls the opening angle, thereby achieving fluid volume control. A pressure testing component is installed on the flow meter of the downhole intelligent injection and production device.

[0118] Once inside the well, the downhole intelligent injection and production device operates according to the set injection volume for a single segment, with the opening time controlled by time. After opening, it automatically adjusts according to the target flow rate. Simultaneously, the water nozzle can be remotely controlled to open. Communication with the surface is achieved through fluid wave codes. The surface establishes flow fluctuations by changing the flow rate inside the wellbore. The downhole intelligent injection and production device detects these flow changes, parses the meaning of the commands, and executes the corresponding actions. While detecting flow fluctuations, the pressure testing component simultaneously tests the wellbore pressure changes, parses the pressure fluctuation commands, and verifies the flow command codes.

[0119] During normal fluid production, the produced fluid from both ends, driven by the pump 100, enters the tubing string through the distributor nozzles, then flows through the produced fluid channel (i.e., the second central channel 401) of the production bridge working barrel 400 and the production screen pipe 701, before being pumped out of the wellhead. If a sudden surge of injected water occurs at a certain production end, causing a rapid increase in water cut, that production end can be shut off via a digital communication nozzle to achieve single injection and single production, preventing water flooding in the horizontal well. Both the distributor nozzle and the digital communication nozzle refer to nozzles installed on the downhole intelligent controller. The nozzles control the opening size to regulate the water flow, and can be electrically shut off to prevent flooding when a risk of flooding occurs.

[0120] The above are merely illustrative embodiments of the present invention and are not intended to limit the scope of the invention. Any equivalent changes and modifications made by those skilled in the art without departing from the concept and principles of the present invention should fall within the scope of protection of the present invention.

Claims

1. A horizontal well simultaneous injection and production tubing string, characterized in that, It includes a sequentially connected oil pump, an upper bridge packer, an oil production bridge working barrel, a lower bridge packer, a hydraulic packer, and a soluble bottom plug; The upper bridge packer has an independent first central channel and a first bridge channel, and an external first rubber sleeve structure that can be set when pressurized in the first central channel. The oil production bridge working barrel has an independent second central channel and a second bridge channel, and a lateral opening that connects the second central channel and the outside of the oil production bridge working barrel is provided on the oil production bridge working barrel. A temporary pipe that can seal the lateral opening is connected to the lateral opening by a temporary shear pin. The lower bridge packer has an independent third central channel and a third bridge channel, and an external second rubber sleeve structure that can be set when pressurized in the third central channel. Wherein, the shearing pressure of the temporary shear pin is greater than the setting pressure of the first rubber sleeve structure, the second rubber sleeve structure and the hydraulic packer; the two ends of the first bridge channel can be connected to the outside of the upper bridge packer and the upper end of the second bridge channel respectively, the lower end of the second bridge channel can be connected to the upper end of the third bridge channel, and the lower end of the third bridge channel can be connected to the outside of the lower bridge packer; The upper bridge packer includes a first diversion tube, a first outer tube sleeved and fixed outside the first diversion tube, a first rubber sleeve structure sleeved on the first outer tube, and a first piston. The inner cavity of the first diversion tube forms the first central channel, and a gap is left between the first outer tube and the first diversion tube, forming the first bridge channel with the upper end closed and the lower end open. The outer wall of the first outer tube has a first limiting part, the upper end of the first rubber sleeve structure can abut against the first limiting part, the upper end of the first piston can abut against the lower end of the first rubber sleeve structure, and the first piston is connected to the first outer tube through a first setting shear pin. A first sealing cavity is formed between the first piston and the first outer tube, and a first liquid inlet is opened on the first diversion tube. The first liquid inlet communicates with the first central channel and the first sealing cavity and is isolated from the first bridge channel. A first anti-reverse ring is also provided between the first piston and the first outer tube and between the first sealing cavity and the first setting shear pin. The first piston can move axially upward in one direction and is connected to the first anti-reverse ring.

2. The horizontal well simultaneous injection and production tubing string as described in claim 1, characterized in that, A lateral water injection hole is provided on the first outer tube and above the first rubber sleeve structure. The lateral water injection hole is connected to the outside of the first bridge-type channel and the upper bridge-type packer.

3. The horizontal well simultaneous injection and production tubing string as described in claim 2, characterized in that, A first stop portion is provided on the outer wall of the first outer tube and below the first sealing cavity. A first unsealing retaining ring is also provided between the first outer tube and the first piston. The two ends of the first anti-reverse ring abut against the first stop portion and the first unsealing retaining ring, respectively. The first unsealing retaining ring is connected to the first outer tube through a first unsealing shear pin.

4. The horizontal well simultaneous injection and production tubing string as described in claim 3, characterized in that, The first outer tube includes a first upper connector, a first sealing sleeve, a first connecting sleeve, a first setting sleeve, and a first lower connector connected sequentially from top to bottom. The middle inner wall of the first upper connector is threadedly sealed to the upper outer wall of the first diverter tube. The lower inner wall of the first upper connector is threadedly sealed to the upper outer wall of the first sealing sleeve. The lower outer wall of the first sealing sleeve is threadedly connected to the upper inner wall of the first connecting sleeve. The lower outer wall of the first connecting sleeve is threadedly connected to the upper inner wall of the first setting sleeve. The lower outer wall of the first setting sleeve is threadedly connected to the upper inner wall of the first lower connector. The inner diameters of the first sealing sleeve, the first connecting sleeve, the first seated sleeve, and the first lower connector are the same, and the inner walls of the four are spaced apart from the outer wall of the first diversion pipe, forming the first bridge-type channel. A first limiting ring is threadedly connected to the outside of the first sealing sleeve, and a gap is left between the first limiting ring and the lower end of the first upper connector. The lateral water injection hole is opened on the first sealing sleeve and is set corresponding to the gap. The lower end of the first limiting ring forms the first limiting part. The first anti-reverse ring and the first unsealing ring are both sleeved on the first seated sleeve. The first unsealing ring is connected to the first seated sleeve through the first unsealing shear pin. A first shearing ring is threadedly sleeved on the lower part of the first seated sleeve and between the first unsealing ring and the first lower connector. The lower end of the first piston is connected to the first shearing ring through the first seated shear pin.

5. The horizontal well simultaneous injection and production tubing string as described in claim 4, characterized in that, The first piston includes a first upper piston tube, a first lower piston tube, and a first locking sleeve arranged in sequence. The upper inner wall of the first upper piston tube is provided with a first upper protruding ring, and the inner wall of the first upper protruding ring can seal and contact the outer wall of the first sealing sleeve. The lower inner wall of the first upper piston tube is threadedly connected to the upper outer wall of the first lower piston tube, and the upper inner wall of the first lower piston tube is provided with a first lower protruding ring, and the inner wall of the first lower protruding ring can seal and contact the outer wall of the first connecting sleeve. A first upper annular cavity is formed between the inner wall of the middle part of the first upper piston tube and the outer wall of the first outer tube. The upper outer wall of the first connecting sleeve is provided with an annular first upper flange protruding outward. The first upper flange is located in the first upper annular cavity, and the outer wall of the first upper flange can be in sealing contact with the inner wall of the first upper piston tube. A first upper sealing cavity is formed between the upper end face of the first upper flange and the lower end face of the first upper annular ring. The upper outer wall of the first seat sleeve is provided with an annular first lower flange protruding outward. The first lower flange can be in sealing contact with the inner wall of the first lower piston tube, and a first lower sealing cavity is formed between the upper end face of the first lower flange and the lower end face of the first lower annular ring. The first upper sealing cavity and the first lower sealing cavity constitute the first sealing cavity. The lower outer wall of the first lower piston tube is internally threaded to the upper end of the first locking sleeve. The lower end face of the first lower flange forms the first stop portion. The lower end of the first locking sleeve is connected to the first shearing retaining ring through the first setting shear pin. A first lower ring cavity is formed between the middle inner wall of the first locking sleeve and the outer wall of the first setting shear sleeve. The first anti-reverse ring and the first unsealing retaining ring are both located in the first lower ring cavity.

6. The horizontal well simultaneous injection and production tubing string as described in claim 5, characterized in that, Multiple first upper through holes are circumferentially spaced at positions corresponding to the first upper sealing cavity on the first sealing sleeve. Multiple first upper arc-shaped blocks are circumferentially spaced at positions on the outer wall of the first diverter tube. Each first upper arc-shaped block has a first upper radial hole, which connects the first central channel and the corresponding first upper through hole. Multiple first lower through holes are circumferentially spaced at positions corresponding to the first lower sealing cavity on the first connecting sleeve. Multiple first lower arc-shaped blocks are circumferentially spaced at positions on the outer wall of the first diverter tube. Each first lower arc-shaped block has a first lower radial hole, which connects the first central channel and the corresponding first lower through hole. The first upper radial hole and the first lower radial hole constitute the first liquid inlet.

7. The horizontal well simultaneous injection and production tubing string as described in claim 2, characterized in that, The oil production bridge-type working cylinder includes a second diversion pipe and a second outer pipe spaced outside the second diversion pipe. The inner cavity of the second diversion pipe forms the second central channel, and the gap between the second outer pipe and the second diversion pipe forms the second bridge-type channel that is open at both ends. Multiple second through holes are circumferentially spaced on the second outer pipe, and multiple second arc-shaped blocks are circumferentially spaced on the outer wall of the second diversion pipe. Each second arc-shaped block has a second radial hole, which connects the second central channel and the corresponding second through hole. The second radial hole and the corresponding second through hole form the lateral opening. The temporary pipe is connected to the second outer pipe through temporary shear pins and can seal and block each of the second through holes. The lower end of the first outer pipe is connected to the upper end of the second outer pipe through a first outer oil pipe, and the lower end of the first shunt pipe is connected to the upper end of the second shunt pipe through a first inner oil pipe. The first oil pipe annulus formed between the first outer oil pipe and the first inner oil pipe can be connected to both the first bridge channel and the second bridge channel.

8. The horizontal well simultaneous injection and production tubing string as described in claim 7, characterized in that, The second diversion pipe includes a first inner tube sealing cylinder and a diversion inner pipe. The lower inner wall of the first inner tube sealing cylinder is threadedly sealed to the upper outer wall of the diversion inner pipe. The first inner oil pipe can be sealed and inserted into the first inner tube sealing cylinder and abut against the upper end surface of the diversion inner pipe. The second arc-shaped block is formed on the diversion inner pipe.

9. The horizontal well simultaneous injection and production tubing string as described in claim 8, characterized in that, The second outer tube includes a second upper connector, a diversion outer tube, and a second lower connector arranged in sequence. The lower inner wall of the second upper connector is threadedly sealed to the upper outer wall of the diversion outer tube. The diversion outer tube is welded and fixed to each of the second arc-shaped blocks. The lower outer wall of the diversion outer tube is threadedly sealed to the upper inner wall of the second lower connector. The inner walls of the second upper connector, the diversion outer tube, and the second lower connector are spaced from the outer wall of the diversion inner tube, forming a second bridge-type channel. The second through hole is opened on the diversion outer tube. The temporary tube is sleeved on the diversion outer tube, and its upper end is sealed to the outer wall of the second upper connector and connected to the second upper connector through the temporary shear pin. Its lower end is sealed to the diversion outer tube and located below the second through hole.

10. The horizontal well simultaneous injection and production tubing string as described in claim 7, characterized in that, The lower bridge packer includes a third diversion pipe, a third outer pipe sleeved and fixed outside the third diversion pipe, and a second rubber sleeve structure and a second piston sleeved on the third outer pipe; the inner cavity of the third diversion pipe forms the third central channel, and there is a gap between the third outer pipe and the third diversion pipe to form the third bridge channel with an open upper end and a closed lower end. A lateral water outlet is provided on the third outer pipe near the lower end of the third bridge channel, and the lateral water outlet communicates with the third bridge channel. The outer wall of the third outer tube has a second limiting part, the upper end of the second rubber sleeve structure can abut against the second limiting part, the upper end of the second piston can abut against the lower end of the second rubber sleeve structure, and the second piston is connected to the third outer tube through a second setting shear pin; a second sealing cavity is formed between the second piston and the third outer tube, and a second liquid inlet is provided on the third diverter tube. The second liquid inlet communicates with the third central channel and the second sealing cavity and is isolated from the third bridge channel; a second anti-reverse ring is also provided between the second piston and the third outer tube and between the second sealing cavity and the second setting shear pin, and the second piston can move axially upward unidirectionally and is connected to the second anti-reverse ring; The lower end of the second outer pipe is connected to the upper end of the third outer pipe through a second outer oil pipe, and the lower end of the second shunt pipe is connected to the upper end of the third shunt pipe through a second inner oil pipe. The second oil pipe annulus formed between the second outer oil pipe and the second inner oil pipe can communicate with both the second bridge channel and the third bridge channel.

11. The horizontal well simultaneous injection and production tubing string as described in claim 10, characterized in that, A second stop is provided on the outer wall of the third outer tube and below the second sealing cavity. A second unsealing retaining ring is also provided between the third outer tube and the second piston. The two ends of the second anti-reverse ring abut against the second stop and the second unsealing retaining ring, respectively. The second unsealing retaining ring is connected to the third outer tube through a second unsealing shear pin.

12. The horizontal well simultaneous injection and production tubing string as described in claim 11, characterized in that, The upper outer wall of the third diversion pipe is threadedly sealed to the lower inner wall of the second inner tube sealing cylinder, and the second inner oil pipe can be sealed and inserted into the second inner tube sealing cylinder and abut against the upper end face of the third diversion pipe.

13. The horizontal well simultaneous injection and production tubing string as described in claim 11, characterized in that, The third outer pipe includes, in order from top to bottom, a third upper connector, a second sealing sleeve, a second connecting sleeve, a second setting sleeve, a water injection screen pipe, and a third lower connector. The upper inner wall of the third upper connector is threadedly connected to the second outer oil pipe. The lower inner wall of the third upper connector is threadedly and sealingly connected to the upper outer wall of the second sealing sleeve. The lower outer wall of the second sealing sleeve is threadedly connected to the upper inner wall of the second connecting sleeve. The lower outer wall of the second connecting sleeve is threadedly connected to the upper inner wall of the second setting sleeve. The lower outer wall of the second setting sleeve is threadedly connected to the upper inner wall of the water injection screen pipe. The lower inner wall of the water injection screen pipe is threadedly connected to the upper outer wall of the third lower connector. The upper inner wall of the third lower connector is threadedly and sealingly connected to the lower outer wall of the third diversion pipe. The inner walls of the third upper connector, the second sealing sleeve, the second connecting sleeve, the second setting sleeve, and the water injection screen pipe are spaced apart from the outer wall of the third diversion pipe, forming the third bridge-type channel. A second limiting ring is threadedly connected to the lower end of the third upper connector outside the second sealing sleeve. The lower end of the second limiting ring forms the second limiting part. The screen holes of the water injection screen pipe form the lateral water outlet. The second anti-reverse ring and the second unsealing ring are both sleeved on the second setting sleeve. The second unsealing ring is connected to the second setting sleeve through the second unsealing shear pin. A second shearing ring is threadedly sleeved at the lower part of the second setting sleeve and between the second unsealing ring and the water injection screen pipe. The lower end of the second piston is connected to the second shearing ring through the second setting pin.

14. The horizontal well simultaneous injection and production tubing string as described in claim 13, characterized in that, The second piston includes a second upper piston tube, a second lower piston tube, and a second locking sleeve arranged sequentially. The upper inner wall of the second upper piston tube has a second upper protruding ring protruding inward, and the inner wall of the second upper protruding ring can seal against the outer wall of the second sealing sleeve. The lower inner wall of the second upper piston tube is threadedly connected to the upper outer wall of the second lower piston tube, and the upper inner wall of the second lower piston tube has a second lower protruding ring protruding inward, and the inner wall of the second lower protruding ring can seal against the outer wall of the second connecting sleeve. A second upper annular cavity is formed between the inner wall of the middle part of the second upper piston tube and the outer wall of the third outer tube. The upper outer wall of the second connecting sleeve is provided with an annular second upper flange. The second upper flange is located in the second upper annular cavity, and the outer wall of the second upper flange can be in sealing contact with the inner wall of the second upper piston tube. A second upper sealing cavity is formed between the upper end face of the second upper flange and the lower end face of the second upper annular ring. The upper outer wall of the second seat sleeve is provided with an annular second lower flange. The second lower flange can be in sealing contact with the inner wall of the second lower piston tube, and a second lower sealing cavity is formed between the upper end face of the second lower flange and the lower end face of the second lower annular ring. The second upper sealing cavity and the second lower sealing cavity constitute the second sealing cavity. The lower outer wall of the second lower piston tube is threadedly connected to the upper inner wall of the second locking sleeve. The lower end face of the second lower flange forms the second stop portion. The lower end of the second locking sleeve is connected to the second shearing retaining ring through the second setting shear pin. A second lower ring cavity is formed between the middle inner wall of the second locking sleeve and the outer wall of the second setting sleeve. The second anti-reverse ring and the second unsealing retaining ring are both located in the second lower ring cavity.

15. The horizontal well simultaneous injection and production tubing string as described in claim 14, characterized in that, Multiple third upper through holes are circumferentially spaced at positions corresponding to the second upper sealing cavity on the second sealing sleeve. Multiple third upper arc-shaped blocks are circumferentially spaced at positions on the outer wall of the third diverter. Each third upper arc-shaped block has a third upper radial hole, which connects the third central channel and the corresponding third upper through hole. Multiple third lower through holes are circumferentially spaced at positions corresponding to the second lower sealing cavity on the second connecting sleeve. Multiple third lower arc-shaped blocks are circumferentially spaced at positions on the outer wall of the third diverter. Each third lower arc-shaped block has a third lower radial hole, which connects the third central channel and the corresponding third lower through hole. The third upper radial holes and the third lower radial holes constitute the second liquid inlet.

16. The horizontal well simultaneous injection and production tubing string as described in claim 10, characterized in that, The portion of the first outer tube located above the first rubber sleeve structure and the portion of the third outer tube located above the second rubber sleeve structure are both made of non-metallic drillable material.

17. The horizontal well simultaneous injection and production tubing string as described in claim 16, characterized in that, A first safety release connector is connected above the upper bridge packer, a second safety release connector is connected above the lower bridge packer, and a third safety release connector is connected above the hydraulic packer.

18. The horizontal well simultaneous injection and production tubing string as described in claim 1, characterized in that, Below the soluble bottom plug, an oil production screen and a plug are sequentially connected.

19. The horizontal well simultaneous injection and production tubing string as described in claim 1, characterized in that, An insertion tube hanger is also connected between the oil pump and the upper bridge packer, and the lower end of the oil pump can be sealed and inserted into the insertion tube hanger.

20. The horizontal well simultaneous injection and production tubing string as described in claim 1, characterized in that, A first soluble centralizer is connected above or below the upper bridge packer, a second soluble centralizer is connected above or below the lower bridge packer, and a third soluble centralizer is connected below the hydraulic packer.

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