Oil and gas well production section annulus self-driving solid sealing pipe joint and well completion structure

Abstract

An oil and gas well production section annulus self-driving solid sealing pipe joint and a well completion structure are applied to an oil and gas well of a single stratum or penetrating through a plurality of stratums, the self-driving solid sealing pipe joint comprises a base pipe, the whole base pipe is of a pipe cavity structure, butt joint devices are arranged at the two ends of the base pipe, and the base pipe can be connected with adjacent pipe joints in a central pipe column in an end-to-end mode; the agent storage device is arranged on the base pipe, a sealing agent is arranged in the agent storage device, the sealing agent can be injected into the shaft annulus, the sealing agent and the continuous packer jointly form a sealing body 200, and the sealing body 200 can prevent liquid in the shaft annulus from axially channeling along the shaft annulus; and the driving device 3 is arranged on the base pipe 1 and is used for driving the agent storage device 2 to inject the sealing agent 20 into the shaft annulus according to an agent injection trigger signal. According to the technical scheme provided by the embodiment of the utility model, the fluid channeling prevention capability of the continuous packer in the wellbore annulus in the oil and gas well production section can be improved, and the crude oil recovery rate is improved.

Description

Technical Field

[0001] This utility model patent belongs to the field of oil and gas extraction technology, and relates to a self-driven solidification pipe section for the annulus of an oil and gas well production section, a self-driven solidification method for the annulus of an oil and gas well production section, and a well completion structure. Background Technology

[0002] In the field of oil and gas extraction technology, for wellbores that penetrate multiple formations, the oil and water fronts of these formations advance at different speeds. The oil and water fronts of the formations with faster advance speeds reach the wellbore first, and these formations are considered high-water-cut formations. Water produced from high-water-cut formations experiences axial flow (inter-layer flow) in the wellbore annulus, which reduces the oil production rate of other formations. On the other hand, for long single-formation production sections, axial flow (intra-layer flow) also exists in the wellbore annulus, affecting the recovery rate of oil and gas wells. To solve this problem, continuous packer water control technology (see Chinese utility model patents 2008100556801, 2014100135988, and 2019100846588) has emerged. The principle is that by running a flow control center string (such as an ICD, AICD, or sliding sleeve flow control center string) into the production section of the wellbore, and filling the annulus formed by the outer wall of the production section center string and the inner wall of the wellbore with solid particles to form a continuous packer, the axial flow of water produced from high water-cut formations in the annulus can be effectively restricted. However, due to the presence of flow-through pores inside the continuous packer, axial flow of produced water cannot be completely eliminated. For example, when the interlayer distance is large (e.g., 30 meters), the interlayer flow of water produced by high water-bearing formations is small (e.g., only 20 cubic meters / day); however, when the interlayer distance is small (e.g., only 10 meters), the interlayer flow is relatively large (e.g., 60 cubic meters / day), resulting in a reduction in oil production (e.g., 15 cubic meters / day); and when the interlayer distance is even smaller (e.g., only 5 meters), the interlayer flow will be even larger (e.g., 60 cubic meters / day), further reducing oil production (e.g., 30 cubic meters / day). Based on this, existing technologies have also proposed a storage-type precision quantitative injection (i.e., solidifying agent) technical solution (see Chinese Utility Model Patent 2015103702195). This involves first storing the required amount of solidifying agent for multiple target solidification points in multiple pre-placed containers. Then, these containers are placed into an injection tubing and lowered into the target solidification point location once or multiple times. The injection is then performed by pressing the tubing through the ground. Once the solidifying agent solidifies, it can seal the flow pores inside the continuous sealing body corresponding to the target solidification point, thereby completely solving the problem of interlayer or intralayer flow in the wellbore annulus.However, this technical solution still has the following problems: First, it still requires running the injection tubing into the central tubing, which is not only complicated but also increases the time and cost of operation; second, the sealant output from the injection tubing needs to pass through the central tubing to enter the wellbore annulus, so the corresponding injection positions on the central tubing need to be pre-set with channels such as check valves for outputting the sealant; third, before the injection tubing injects sealant into the wellbore annulus, packers need to be used to seal both ends of the injection position in the annulus formed by the outer wall of the injection tubing and the inner wall of the central tubing. This ensures that the solidifying agent can smoothly enter the wellbore annulus, rather than flowing arbitrarily axially within the tubing annulus. These issues undoubtedly increase the complexity of the equipment and process, while also posing higher construction risks and economic costs. Fourth, since the injection tubing needs to be lowered into the wellbore production section from inside the central tubing, the outer diameter of the injection tubing (and its attached packer) must be smaller than the inner diameter of the central tubing. Furthermore, the container needs to be placed inside the injection tubing, which severely limits the container's external dimensions, resulting in a very limited capacity for the solidifying agent it can carry. Utility Model Content

[0003] The purpose of this utility model is to overcome the defects of the prior art and provide a self-driven solidified sealing pipe section, solidification method and completion structure for the annulus of the production section of an oil and gas well, which can improve the anti-channeling ability of the continuous sealing body in the annulus of the wellbore in the production section of an oil and gas well and improve the crude oil recovery rate.

[0004] To achieve the above objectives, the present invention adopts the following technical solution:

[0005] A self-driven solidification sealing tube section for the annulus of an oil and gas well production section is applicable to oil and gas wells in single formations or those penetrating multiple formations. The production section wellbore contains a central tubing string, and an annulus is defined between the wellbore wall and the central tubing string. A continuous packer formed by the accumulation of packing particles is disposed within the annulus. The central tubing string includes the self-driven solidification sealing tube section, which comprises: a base tube 1, which has an overall tubular structure and is equipped with docking devices 11 at both ends for end-to-end connection with adjacent tube sections in the central tubing string; and a storage device 2, which is equipped with... The reservoir 2, located on the base pipe 1, contains a solidifying agent 20. Under external driving action, the reservoir 2 can inject the solidifying agent 20 into the wellbore annulus. The solidifying agent 20 can enter the flow pores of the continuous packer and solidify, forming a solidified body 200 together with the continuous packer. The solidified body 200 can prevent the liquid in the wellbore annulus from flowing axially along the wellbore annulus. The driving device 3, located on the base pipe 1, is used to drive the reservoir 2 to inject the solidifying agent 20 into the wellbore annulus according to the injection trigger signal.

[0006] To achieve the above objectives, the present invention also adopts the following technical solution:

[0007] A self-driven solidification method for the annulus of an oil and gas well production section, using the self-driven solidification tubing section of the oil and gas well production section as described above, includes the following steps: (1) prefabricating the self-driven solidification tubing section carrying solidification agent 20 on the central tubing string; wherein, the position of the self-driven solidification tubing section relative to the central tubing string corresponds to the position of the target solidification point in the wellbore; (2) running the central tubing string into the wellbore; (3) the driving device driving the storage device to inject the solidification agent 20 into the wellbore annulus according to the injection trigger signal; (4) the solidification agent 20 enters the flow pores of the continuous packer in the wellbore annulus and solidifies, forming a solidification body 200 together with the continuous packer, the solidification body 200 being able to prevent the liquid in the wellbore annulus from flowing axially along the wellbore annulus.

[0008] To achieve the above objectives, the present invention also adopts the following technical solution:

[0009] A well completion structure is applied to oil and gas wells in a single formation or through multiple formations. The well completion structure includes a central tubing string disposed in the production section of the wellbore. An annulus is defined between the wellbore wall of the production section and the central tubing string. A continuous packer formed by the accumulation of packing particles is disposed in the annulus. The central tubing string is characterized in that it includes the self-driven solid seal section as described above.

[0010] This utility model discloses a self-driven solidification tube section, solidification method, and completion structure for the annulus of an oil and gas well production section. Compared with the existing fixed-point isolation method using the injection string, it offers several advantages: First, the self-driven solidification tube section is run along with the central tubing into the wellbore production section, reducing the need for additional injection tubing runs and improving efficiency. Second, the self-driven solidification tube section's dimensions are largely consistent with the other sections of the central tubing, reducing the risk of the injection string encountering obstructions and being unable to be run or pulled up, while also enabling one-time completion operations for multiple target solidification points. Third, the self-driven solidification tube section's position relative to the central tubing is fixed, allowing for accurate positioning of the target isolation location. Fourth, the self-driven solidification tube section has its own drive device, eliminating the need for control drive cables on the central tubing. Through electronic or mechanical automatic control methods integrated within the device, it achieves self-drive and self-control of the device's operation, resulting in a simple structure and ease of use. Fifth, the capacity of the sealing agent can be pre-set, thereby achieving quantitative injection and sealing of the sealing agent. While ensuring the sealing effect, it avoids injecting too much sealing agent and losing the oil-producing formation, and also avoids injecting too little sealing agent and failing to achieve the expected sealing effect. Sixth, the use of a trigger control method can be combined with the well completion operation process to precisely control the injection time of the sealing agent, thereby improving the overall work efficiency of the well completion operation. Seventh, it supports the use of two-component sealing agents, ensuring that the solidification time of the sealing agent after injection into the wellbore annulus can be precisely controlled. Attached Figure Description

[0011] Figure 1 This is a cross-sectional view of the overall structure of an annular self-driven solid seal pipe section in the production section of an oil and gas well, as shown in Example 2.

[0012] Figure 2 yes Figure 1 Cross-sectional view along the AA direction;

[0013] Figure 3 yes Figure 1 Cross-sectional view along the BB direction;

[0014] Figure 4 This is a cross-sectional view of the overall structure of an annular self-driven solidification pipe section in the production section of an oil and gas well before the solidification agent is injected, as shown in Example 1.

[0015] Figure 5 This is a cross-sectional view of the overall structure of an annular self-driven solid seal pipe section in the production section of an oil and gas well, as shown in Example 3.

[0016] Figure 6 This is a cross-sectional view of the overall structure of an annular self-driven solidification pipe section in the production section of an oil and gas well after the solidification agent has been discharged, as shown in Example 3.

[0017] Figure 7 This is a cross-sectional view of the overall structure of an annular self-driven solid seal pipe section in the production section of an oil and gas well, as shown in Example 4.

[0018] Figure 8 This is a cross-sectional view of the overall structure of an annular self-driven solidification pipe section in the production section of an oil and gas well after the solidification agent has been discharged, as shown in Example 4.

[0019] Figure 9 This is a cross-sectional view of the overall structure of another type of oil and gas well production section annulus self-driven solid seal pipe section in Example 4;

[0020] Figure 10 This is a cross-sectional view of the overall structure of another type of oil and gas well production section annulus self-driven solidification pipe section after the solidification agent is discharged, as shown in Example 4.

[0021] Figure 11 This is a cross-sectional view of the overall structure of an annular self-driven solid seal pipe section in the production section of an oil and gas well, as shown in Example 5.

[0022] Figure 12 This is a cross-sectional view of the overall structure of an annular self-driven solidification pipe section in the production section of an oil and gas well after the solidification agent has been discharged, as shown in Example 5.

[0023] Figure 13 This is a cross-sectional view of the overall structure of an annular self-driven solid seal pipe section in the production section of an oil and gas well, as shown in Example 5.

[0024] Figure 14This is a cross-sectional view of the overall structure of an annular self-driven solidification pipe section in the production section of an oil and gas well after the solidification agent has been discharged, as shown in Example 5.

[0025] Figure 15 This is a cross-sectional view of the overall structure of an annular self-driven solid seal pipe section in the production section of an oil and gas well, as shown in Example 6.

[0026] Figure 16 yes Figure 15 Cross-sectional view along the AA direction;

[0027] Figure 17 yes Figure 15 Cross-sectional view along the BB direction;

[0028] Figure 18 yes Figure 15 Cross-sectional view along the CC direction;

[0029] Figure 19 This is a cross-sectional view of the overall structure of an annulus self-driven solid seal pipe section in the production section of an oil and gas well before glue injection, as shown in Example 6.

[0030] Figure 20 This is a schematic diagram of the well completion structure before solidification in Example 8;

[0031] Figure 21 This is a schematic diagram of the well completion structure after solidification in Example 8.

[0032] Explanation of reference numerals in the attached drawings: 1-base tube, 11-docking device, 2-storage device, 20-sealant, 20-1-first sealant, 20-2-second sealant, 200-sealant body, 21-storage chamber, 22-piston, 221-sealing ring, 222-slider, 23-discharge connector, 231-filling port, 231-1-first filling port, 231-2-second filling port, 232-discharge port, 233-filter screen, 234-sealant mixing device, 24-pressure space, 25-partition plate, 26-storage bladder, 3-drive device, 31-control circuit, 32-battery, 33-drive 34-Plunger pump, 35-Inlet connector, 351-Plunger pump inlet channel, 352-Plunger pump outlet channel, 353-Injection pressure balance port, 353-1-First injection pressure balance port, 353-2-Second injection pressure balance port, 36-Expansion material, 360-Elastic accumulator, 361-Limiting device, 362-Controller, 363-Release device, 37-Liquid-contact control valve, 4-Pressure-bearing outer jacket, 41-Electrical control compartment, 42-Electric compartment, 43-Communication port, 44-Extension fixing part, 45-Elastic drive device compartment, 46-Expansion material compartment, 5-Self-driven solid seal pipe section. Detailed Implementation

[0033] The following is in conjunction with the appendix Figure 1-21This invention further illustrates the specific implementation of a self-driven solid seal tube section for sealing the wellbore annulus, a method for sealing the wellbore annulus, and a completion structure according to the present invention. The self-driven solid seal tube section for sealing the wellbore annulus, a method for sealing the wellbore annulus, and a completion structure according to the present invention are not limited to the descriptions in the following embodiments.

[0034] First, the application scenario of this patent will be explained. For oil and gas wells penetrating multiple formations, due to the different advance speeds of the oil and water fronts in the various formations after production, the oil and water fronts of the formations with faster advance speeds reach the wellbore first, and this formation becomes a high water-cut formation. For wellbores containing locally high water-cut formations, because water has a much higher fluidity than oil, the produced water from the high water-cut formation will flow axially towards the adjacent formations at both ends in the wellbore annulus, i.e., inter-layer flow. When the water reaches the high water-cut formation and the corresponding production screens of the adjacent formations at both ends, due to the superior fluidity of water, a large amount of water will pass through the production screens into the central tubing and be produced, causing a sharp increase in the water content of the produced fluid. On the other hand, due to the large amount of water produced, the pressure difference between the inside and outside of the central tubing decreases, which will further inhibit the production of oil in the formation matrix. Therefore, in order to reduce the water content of the produced fluid and increase oil production, it is necessary to isolate the locally high water-cut formations in the wellbore, especially to suppress the flow of water in the wellbore annulus.

[0035] Example 1:

[0036] This embodiment provides a specific implementation method for a self-driven solidified sealing pipe section in the annulus of an oil and gas well production section.

[0037] refer to Figure 1-19 As shown, an annulus self-driven solidification tubing section for oil and gas well production sections is used in oil and gas wells with single formations or those penetrating multiple formations. The production section wellbore contains a central tubing string, and an annulus is formed between the wellbore wall and the central tubing string. A continuous packer, formed by the accumulation of packing particles, is located within the annulus. The central tubing string includes the self-driven solidification tubing section, which comprises: a base pipe 1, which has an overall tubular structure and is equipped with docking devices 11 at both ends, enabling end-to-end connection with adjacent tubing sections in the central tubing string; and a storage device 2. The reservoir 2, mounted on the base pipe 1, contains a solidifying agent 20. Under external driving action, the reservoir 2 can inject the solidifying agent 20 into the wellbore annulus. The solidifying agent 20 can enter the flow pores of the continuous packer and solidify, forming a solidified body 200 together with the continuous packer. The solidified body 200 can prevent the liquid in the wellbore annulus from flowing axially along the wellbore annulus. The driving device 3, mounted on the base pipe 1, is used to drive the reservoir 2 to inject the solidifying agent 20 into the wellbore annulus according to the injection trigger signal.

[0038] Specifically, the base pipe 1 can be in the form of a standard short section or a screen pipe, with the storage device 2 and drive device 3 located in the blind section of the screen pipe. Different lengths of base pipe 1 can be preset to adapt to different target solidification point locations, providing greater flexibility in use. The diameter of the self-driven solidification pipe section is consistent with the outer diameter of other pipe sections of the central tubing, such as the screen pipe, effectively preventing obstruction during the running of the central tubing. The length of a single section of the self-driven solidification pipe section can be set according to the capacity requirements of the solidification agent 20 stored inside the storage device 2 and the space occupied by the drive device 3, meeting the requirements for setting larger capacities of solidification agent 20. The docking device 11 can refer to existing tubing structures, using existing threaded connections or snap-fit ​​methods. The position of the self-driven solidification pipe section in the central tubing is consistent with the position of the target solidification point (e.g., both sides of a high water-cut formation, or several locations in a long but isolated production section of the formation). The wellbore structure of the central tubing can be planned and designed based on logging data before the central tubing is run into the well. The target solidification point refers to the location in the wellbore where isolation is required, pre-set by the user based on the downhole formation conditions. After the central tubing is run into the well, isolation operations are performed using the self-driven solidification tubing section. Solidification agent 20 can be used to seal the annulus at the target solidification point, thereby isolating, for example, high water-cut formations from other formations. The injection trigger signal is the signal that guides the drive device 2 to activate the storage device 2 to inject the solidification agent 20 into the annulus. The injection trigger signal can be generated in various ways, such as from the surface via a control line connected to the surface, or by pressure control. For example, after the central tubing reaches the corresponding formation, it will be subjected to pressure from underground fluids; the injection trigger signal is generated by identifying this pressure value. Another example is manually increasing the downhole pressure from the wellhead into the central tubing or wellbore through injection, and generating the injection trigger signal by identifying this pressure value. The solidifying agent 20 can be in the form of a self-curing adhesive, and the time from preparation to solidification can be set to 8 to 48 hours, depending on the well completion operation procedures. The solidifying agent 20 can also be a liquid-reactive material, such as one that can react with downhole fluids to block the flow pores of the continuous packer. The solidifying agent 20 can also be a dissolving material, such as one that can dissolve the packing particles that form the continuous packer, making the packing particles fuse into a whole, thereby eliminating its flow pores.

[0039] As an optional implementation, the injection trigger signal is generated by a trigger located inside the drive device 3.

[0040] Specifically, since operations such as well washing and filling the wellbore annulus with packer particles are involved after the central tubing string is run into the well, it is necessary to precisely control the injection time of the packer agent 20 into the self-driven solidification tubing section to ensure the operational sequence between different procedures. The trigger can be an electronic or mechanical timer, and its specific structure and implementation method can refer to existing technologies. The advantage of the solution proposed in this embodiment is that, compared with the control line method connected to the surface, there is no need to lay control lines, which not only reduces costs but also avoids the occurrence of packer failure due to damage to the control lines during the well run-in process; compared with the pressure control method, it can achieve more precise control, and is simple to operate, saving costs. Since the self-driven solidification tubing section proposed in this embodiment has its own drive device 3 and trigger (timer), it can achieve "automatic drive" or "self-drive" after running into the well, as well as "self-drive" in the title of this patent.

[0041] As an optional implementation, the self-driven solid seal pipe section further includes a pressure-bearing outer sleeve 4, which is a cylindrical structure and is disposed on the outside of the base pipe 1; the storage device 2 and the driving device 3 are disposed in the pipe section annulus formed by the inner wall of the pressure-bearing outer sleeve 4 and the outer wall of the base pipe 1.

[0042] Specifically, the outer diameter of the pressure-bearing outer sleeve 4 is the same as or smaller than the outer diameter of the screen pipe. This ensures that the central tubing will not encounter obstruction due to an excessively large outer diameter of the self-driven solidified tubing section during the well run-in process. Preferably, the pressure-bearing outer sleeve 4 is coaxially arranged with the base pipe 1, forming a standard annular structure that facilitates the installation of other components inside. The pressure-bearing outer sleeve 4 can be a one-piece structure or a structure composed of multiple sleeves. Its function is to form the reservoir 2, install and protect the drive device 3 and other related devices. Of course, the pressure-bearing outer sleeve 4 is not limited to a standard cylindrical structure. It can also be combined with the base pipe 1 to form other shapes. For example, an axial baffle can be set in the inner part of the base pipe 1 to divide the interior of the base pipe 1 into two spaces, one space serving as a production channel and the other space serving as the annular space of the tubing section. The technical effect achieved is the same as in this embodiment, and it should be considered to belong to the same technical solution as this embodiment.

[0043] The working process of this device is as follows: First, a solidifying agent 20 is provided on the ground and placed in the reservoir 2. Then, the self-driven solidifying tubing section is assembled into a central tubing string and lowered into a predetermined position in the wellbore production section. According to the injection trigger signal, the drive device 3 drives the reservoir 2 to inject the solidifying agent 20 into the wellbore annulus. The solidifying agent 20 enters the flow-through pores of the continuous packer in the wellbore annulus and solidifies, forming a solidified body 200 together with the continuous packer. The solidified body 200 can prevent the liquid in the wellbore annulus from flowing axially along the wellbore annulus.

[0044] It should be further explained that Example 1 proposes an overall implementation method of an annular self-driven solid seal pipe section in the production section of an oil and gas well, while Examples 2 to 6 below are more specific viewing methods based on the utility model concept of Example 1. These examples can be used to illustrate and explain each other, and can be combined with each other to form further technical solutions.

[0045] Example 2:

[0046] Based on the aforementioned embodiments, this embodiment provides a specific implementation method for a self-driven solid seal pipe section in the annulus of an oil and gas well production section.

[0047] like Figure 1-4 As shown, in an optional embodiment, the storage device 2 includes a storage chamber 21 defined by a portion of the inner wall of the pressure-bearing jacket 4 and a portion of the outer wall of the base tube 1. A piston 22 is provided at one end of the storage chamber 21 near the driving device 3, and a dispensing connector 23 is provided at the other end. The piston 22 is generally annular, with its inner and outer annular surfaces slidingly sealing against the outer wall of the base tube 1 and the inner wall of the pressure-bearing jacket 4, respectively, allowing it to move axially within the storage chamber 21 under external force. The dispensing connector 23 connects and fixes the end of the pressure-bearing jacket 4 to the base tube 1 and closes the end of the storage chamber 21. The dispensing connector 23 has an inlet 231 and an outlet 232, used for injecting the sealing agent 20 into the storage chamber 21 and discharging the sealing agent 20 from the storage chamber 21, respectively.

[0048] Specifically, the storage tank 21 is used to store the solidifying agent 20. Based on the logging data of the target solidification point and the distance of the wellbore to be sealed, a suitable capacity of solidifying agent 20 can be pre-filled in the storage tank, without requiring the entire tank to be filled with solidifying agent 20. Furthermore, when the capacity of the entire tank of solidifying agent 20 is insufficient to meet the sealing requirements of a target solidification point, a longer self-driven solidification tube section can be selected to obtain a larger solidifying agent capacity, or two or more self-driven solidification tube sections can be used in series for coordinated operation. Preferably, sealing rings 221 can be provided on the inner and outer annular surfaces of the piston 22 in contact with a portion of the inner wall of the pressure-bearing outer sleeve 4 and a portion of the outer wall of the base pipe 1, thereby improving the sealing effect of the piston 22. The piston 22 can be made of a hard structure such as metal, a soft rubber or nylon structure, or a rubber / nylon-wrapped metal structure, etc., as long as it serves a sealing function and reciprocating motion function, it can meet the requirements. The piston 22 functions to seal the end of the storage chamber 21 and to change the volume of the storage chamber 21, thereby enabling the injection or discharge of the sealing agent 20 into the storage chamber 21. The dispensing connector 23 is an overall annular structure, serving three purposes: first, to support and fix the end of the pressure-bearing outer sleeve 4; second, to seal with the end of the pressure-bearing outer sleeve 4 and the base tube 1, thus forming a closed storage chamber 21; and third, it has an inlet 231 and an outlet 232 formed inside, enabling inlet and outlet functions. See details. Figure 1 and Figure 4 These are schematic diagrams showing the planned discharge of the solidifying agent 20 after the self-driven solidifying pipe section is run into the well and the planned injection of the solidifying agent 20 before running into the well. Preferably, one-way valves can be installed in the injection port 231 and the discharge port 232 to ensure that the solidifying agent 20 can only be discharged according to the specified procedure. Figure 1 , Figure 4 The flow direction of the arrow indicates whether the solidifying agent 20 is being discharged into the wellbore annulus or injected into the storage tank 21. Preferably, multiple outlets 232 (e.g., 3 or 4) can be evenly arranged along the circumference to ensure uniform circumferential injection of the solidifying agent into the wellbore annulus. Preferably, a filter screen 233 can also be provided on the outlet 232 to prevent particles in the wellbore annulus from entering the outlet 232. After the solidifying agent 20 is injected into the wellbore annulus, it will enter the flow pores of the continuous packer and solidify, thereby sealing the wellbore annulus at that location and preventing fluid from passing through the annulus region. This enhances the sealing capacity of the wellbore annulus and improves the oil well recovery rate.

[0049] As an optional implementation, the drive device 3 includes a control circuit 31, a battery 32, a drive motor 33, and a plunger pump 34. The control circuit 31 has a trigger internally configured to generate an injection trigger signal at a specified time according to user settings; or, the control circuit 31 has a pressure detection device internally configured to detect pressure waves generated by surface filling and generate an injection trigger signal based on the pressure waves. The control circuit 31 also controls the drive motor 33 to operate based on the injection trigger signal. The battery 32 supplies power to the control circuit 31. The drive motor 33 receives control from the control circuit 31 and drives the plunger pump 34. The plunger pump 34 receives drive from the drive motor 33 to inject liquid from the annulus into the sealed pressure space 24 on the side of the piston 22 away from the outlet joint 23, driving the piston 22 to move towards the outlet joint 23, thereby discharging the solidifying agent 20 from the storage tank 21 through the outlet 232.

[0050] Specifically, the control circuit 31 can adopt an embedded system structure such as a microcontroller. The system is started before the central tubing is run into the well. The control circuit 31 receives trigger parameters set by the user. The trigger is an electronic timer set inside the embedded system. The electronic timer performs timing / counting in the form of a relative time value (e.g., after 8 hours) or an absolute time value (e.g., XXXX year XX month XX day XX hour XX minute). After the central tubing is run into the well, when the preset time is reached, the trigger inside the control circuit 31 generates an injection trigger signal. The control circuit 31 starts the drive motor 33 to run, which in turn drives the plunger pump 34 to run. Preferably, after the drive motor 33 has run for a certain period of time and all the solidifying agent 20 has been injected into the wellbore annulus, the control circuit 31 stops the drive motor 33 from running. As an optional method for generating injection trigger signals, the trigger is not a timer, but a pressure sensor component logically set on the control circuit 31. The pressure sensor component can be mounted on the circuit board of the control circuit 31 or installed in other locations on the device via leads. Its function is to detect downhole pressure. For example, when a certain pressure value is detected, it can be considered that the central tubing has reached a predetermined position, or when a certain pressure value is detected at the wellhead, it can be considered that the triggering conditions are met. The embedded system generates an injection trigger signal based on the pressure value and a preset program, which can then start the plunger pump 34, either immediately or after a certain delay. The control circuit 31, the battery 32 driving the motor 33, and the plunger pump 34 can adopt specific structures found in the prior art, and should employ appropriate components capable of adapting to high-temperature and high-pressure conditions downhole.

[0051] As an optional implementation, the drive device 3 further includes an inlet connector 35, which is fixedly and sealed to the annulus of the pipe section. The inlet connector 35, the piston 22, the inner wall of the pressure-bearing outer sleeve 4, and the outer wall of the base pipe 1 define a sealed pressure space 24. The inlet connector 35 is provided with a plunger pump inlet channel 351 and a plunger pump outlet channel 352. The plunger pump inlet channel 351 connects the inlet of the plunger pump 34 and the wellbore annulus. The plunger pump outlet channel 352 connects the outlet of the plunger pump 34 and the sealed pressure space 24.

[0052] Specifically, the liquid inlet connector 35 has three functions: firstly, the pressure-bearing outer sleeve 4 adopts a split design, that is... Figure 1 The left side of the middle section forms the storage tank 21, and the right side forms the electrical control compartment 41 and the electric control compartment 42. The liquid inlet connector 35 is used on the right side of the pressure-bearing jacket 4 corresponding to the storage tank 21 section and on the left side of the pressure-bearing jacket 4 corresponding to the electrical control compartment 41 section to achieve support and fixation; secondly, it seals with the pressure-bearing jacket 4 and the base pipe 1 to form the storage tank 21, the sealed pressure space 24, the electrical control compartment 41 and other structures; thirdly, it internally forms the plunger pump inlet channel 351, the plunger pump outlet channel 352, the filling balance pressure port 353 and other structures. Among them, the plunger pump inlet channel 351 and the plunger pump outlet channel 352 can be equipped with one-way valves to ensure that the solidifying agent can only be applied according to the specified amount. Figure 1 , Figure 4 The flow direction is indicated by the middle arrow. The filling pressure balance port 353 is used to discharge air from the sealed pressure space 24 when filling the storage tank 21 with the solidifying agent 20, ensuring pressure balance. It should be further noted that the names 24 and 21 are not names of absolute locations in the device, but rather names based on function. Their physical spatial areas overlap, and their sizes change synchronously with the movement of the piston.

[0053] As an optional implementation, the side of the tube segment annulus formed by the inner wall of the pressure-bearing jacket 4 and the outer wall of the base tube 1 away from the storage tank 21 further includes an electrical control compartment 41 and an electric motor compartment 42. The axial ends of the electrical control compartment 41 and the electric motor compartment 42 are defined and sealed by the extension fixing part 44 from the end of the pressure-bearing jacket 4 towards the base tube 1 and the liquid inlet connector 35. The electrical control compartment 41 is used to house the control circuit 31 and the battery 32 that supplies power to the control circuit 31. The electric motor compartment 42 is used to house the drive motor 33 and the plunger pump 34.

[0054] Specifically, by housing components such as the control circuit 31, battery 32, drive motor 33, and plunger pump 34 within the sealed electrical control compartment 41 and electric control compartment 42, two advantages are achieved: first, ensuring the safety and reliability of these components during the well run-in process, preventing damage; and second, avoiding contact corrosion from downhole produced fluids, ensuring recyclability. Preferably, the extension fixing part 44 is also equipped with a communication port 43, which is electrically connected to the control circuit 31. This communication port 43 is used to send trigger parameters and other information to the control circuit 31 before the self-driven solidified pipe section is run-in. The electrical control compartment 41 and electric control compartment 42 can be distributed longitudinally or side-by-side along the axial direction; this patent does not limit this arrangement.

[0055] This embodiment employs an electronically controlled and piston-driven method to output the sealing agent 20. Firstly, by pre-setting the timing parameters of the trigger, the time and duration of the sealing agent output can be accurately controlled. At the same time, the output power of the plunger pump 34 can also be accurately controlled, thereby accurately controlling the discharge rate and quantity and avoiding incomplete discharge. Secondly, the electronically controlled drive structure technology is relatively mature, highly reliable, and has a low overall cost.

[0056] Example 3:

[0057] Based on the aforementioned embodiments, this embodiment provides a specific implementation method for a self-driven solid seal pipe section in the annulus of an oil and gas well production section.

[0058] like Figure 5-6 As shown, in one optional implementation, the driving device 3 includes an elastic accumulator 360, a limiting device 361, a controller 362, and a releaser 363. The controller 362 has a trigger internally configured to generate an injection trigger signal at a specified time according to user settings, and to control the releaser 363 to release the limiting device 361 based on the injection trigger signal. The releaser 363 is used to receive control from the controller 362 and release the limiting device 361. One end of the elastic accumulator 360 is fixed, and the other end is a free end, with the free end extending in the direction of the piston 22. See also... Figure 5 The elastic energy storage device 360 ​​is in a compressed state in the initial state, and its extension is limited by the limiting device 361; see also Figure 6 When the limiting device 361 is released by the releaser 363, the free end of the elastic storage device 360 ​​extends outward and drives the piston 22 to move toward the dispensing connector 23, thereby discharging the solidifying agent 20 in the storage chamber 21 through the dispensing port 232.

[0059] Specifically, the only difference between this embodiment and Embodiment 2 is the structure of the driving device 3. For other parts not described, please refer to Embodiment 2. The elastic energy storage device 360 ​​utilizes the elasticity of materials such as metal to store energy, which is used to push the piston 22 to discharge the sealing agent 22. The elastic energy storage device 360 ​​can be a ring spring or a shape memory metal structure. The controller 362 can be electronic or mechanical, as detailed below. The release device can also be electronically or mechanically controlled. For example, referring to the technical principles of Chinese Patents 2023219510180 and 2020115538277, the release device uses circuit driving and electromagnetic release methods; another example is referring to the technical principles of Chinese Patents 2020103202316, which stores energy through a spring or clockwork mechanism to drive the mechanical release mechanism. The energy stored in the elastic energy storage device 360 ​​should be sufficient to push the piston 22 to its furthest point, thereby ensuring that all the sealing agent 20 is discharged.

[0060] As an optional implementation, the trigger set in the controller 362 is an electronic timer or a mechanical timer.

[0061] Specifically, the trigger installed in the controller 362 is an electronic timer. Referring also to Chinese patents 2023219510180 and 2020115538277, it can be a self-powered embedded system with an internal electronic timer. Alternatively, the trigger can be a mechanical timer, such as a gear system driven by a spring. Upon reaching the timing period, the electronic timer generates an electronic injection trigger signal, which is transmitted to the controller 362; or the mechanical timer generates an action of a component as an injection trigger signal, and the action of the component serves as the release action of the release device 363, or the action of the component triggers the release device 363 to perform a release action.

[0062] As an optional implementation, the side of the tube segment annulus formed by the inner wall of the pressure-bearing jacket 4 and the outer wall of the base tube 1 away from the storage tank 21 also includes an elastic drive device compartment 45. The axial ends of the elastic drive device compartment 45 are defined and sealed by the extension fixing part 44 from the end of the pressure-bearing jacket 4 to the base tube 1 and the liquid inlet connector 35. The elastic energy storage device 360, the limiting device 361, the controller 362 and the release device 363 are disposed in the elastic drive device compartment 45.

[0063] Specifically, by placing the elastic energy storage device 360, limiting device 361, controller 362, and release device 363 within the elastic drive device compartment 45, two advantages are achieved: first, to ensure the safety and reliability of the relevant components during the well running process, preventing damage; and second, to avoid contact corrosion from downhole production fluids, ensuring recyclability. Preferably, the extension fixing part 44 is also provided with a communication port 43, which is used by the user to set the parameters of the timer inside the controller 362 before the central tubing is run into the well. This can be done electronically or mechanically.

[0064] As an optional implementation, the elastic energy storage device 360 ​​is a spring structure.

[0065] Specifically, the energy stored in the elastic energy storage device 360 ​​should be sufficient to push the piston 22 to its furthest point, thereby ensuring that all the sealant 20 can be discharged.

[0066] This embodiment employs a flexible energy storage device 360° drive and a piston drive to output the sealing agent 20. Compared to the electronic control technology disclosed in Embodiment 2, this avoids bringing batteries, circuit boards, and other structures downhole, thus reducing pollution. Furthermore, the purely mechanical drive device 3 offers better reliability and lower cost, making it highly suitable for the downhole environment during oil and gas well production.

[0067] Example 4:

[0068] Based on the aforementioned embodiments, this embodiment provides a specific implementation method for a self-driven solid seal pipe section in the annulus of an oil and gas well production section.

[0069] like Figure 7-10 As shown, in an optional embodiment, the storage device 2 is a storage bladder 26, which is disposed in a storage chamber 21 defined by a portion of the inner wall of the pressure-bearing outer jacket 4 and a portion of the outer wall of the base tube 1. The opening of the storage bladder 26 is connected to a dispensing connector 23. The dispensing connector 23 connects and fixes the end of the pressure-bearing outer jacket 4 to the base tube 1 and closes the end of the storage chamber 21. The dispensing connector 23 has a dispensing port 232 inside for discharging the sealing agent 20 from the storage bladder 26.

[0070] Specifically, the only difference between this embodiment and Embodiment 2 is the structure of the storage device 2. For other parts not described, please refer to Embodiment 2. According to the technical solution disclosed in Embodiment 2, when using the self-driven solidification tubing section disclosed in Embodiment 2, the user needs to inject solidification agent 20 into the storage tank 21 on-site from the wellhead, which inevitably affects construction efficiency and prolongs the construction period. In this embodiment, the storage device 2 is a storage bladder 26. It can be considered as one or more storage bladders 26 set in the space of the storage tank 21, based on the storage tank 21 disclosed in Embodiment 2. The storage bladder 26 can be a rubber structure, such as a rubber bladder; or it can be a soft metal structure, such as a toothpaste tube-like structure. Simultaneously, the opening of the storage bladder 26 is connected to the dispensing connector 23, the principle and implementation of which are described in Embodiment 2. The technical advantage of this embodiment is that users can prefabricate the reservoir capsule 26 in non-oil and gas well environments such as factories. For example, it can be manufactured in a toothpaste-like form with a toothpaste cap (cap). During field use, the reservoir capsule 26 is directly inserted into the space of the reservoir chamber 21, the cap is removed, and the opening is connected to the dispensing connector 23 to complete the well preparation work. This improves work efficiency and avoids leakage or contamination of the sealing agent during field injection. Figure 7 The diagram shown is a schematic representation of this embodiment before the sealing agent 20 is discharged. Figure 8 The image shows the state of the reservoir 26 after the sealing agent 20 has been discharged. At this point, the reservoir 26 may be compressed near the dispensing connector 23 under fluid pressure, or it may naturally deflate and be contained within the reservoir chamber 21. When implementing this technical solution, some sealing agent 26 may remain inside the reservoir 26, but this will not affect the final sealing effect.

[0071] like Figure 7-8 As shown, in one optional implementation, the drive device 3 includes a control circuit 31, a drive motor 33, and a plunger pump 34. The control circuit 31 has a trigger internally configured to generate an injection trigger signal at a specified time according to user settings; or, the control circuit 31 has a pressure detection device internally configured to detect pressure waves generated by surface filling and generate an injection trigger signal based on the pressure waves. The control circuit 31 also controls the drive motor 33 to operate according to the injection trigger signal. The drive motor 33 is controlled by the control circuit 31 to drive the plunger pump 34. The plunger pump 34 is driven by the drive motor 33 to inject liquid from the wellbore annulus into the reservoir 21, thereby discharging the solidifying agent 20 from the reservoir 26 through the outlet 232.

[0072] Specifically, the structure and working principle of the driving device 3 are the same as in Embodiment 2, the only difference being the process by which the plunger pump 34 drives the solidifying agent 20 to be discharged. In this embodiment, since the storage chamber 21 is a sealed space, when the plunger pump 34 pumps liquid into the storage chamber 21, the internal pressure of the storage chamber 21 increases and is transmitted to the storage bladder 26, thereby compressing the storage bladder 26 and discharging the solidifying agent 20 inside.

[0073] like Figure 9-10 As shown, in an optional implementation, the driving device 3 includes an elastic accumulator 360, a limiting device 361, a controller 362, and a releaser 363. The controller 362 has a trigger internally configured to generate an injection trigger signal at a specified time according to user settings, and to control the releaser 363 to release the limiting device 361 based on the injection trigger signal. The releaser 363 is controlled by the controller 362 to release the limiting device 361. One end of the elastic accumulator 360 is fixed, and the other end is a free end, with the free end extending towards the reservoir 26. Initially, the elastic accumulator 360 is in a compressed state, its extension restricted by the limiting device 361. When the limiting device 361 is released by the releaser 363, the free end of the elastic accumulator 360 extends towards the reservoir 26 and squeezes the reservoir 26, thereby discharging the sealing agent 20 from the reservoir 26 through the outlet 232.

[0074] Specifically, this embodiment employs a purely mechanical structure—storing the sealant 20 in the reservoir 26 and discharging the sealant 20 via the elastic energy storage device 360—which can be considered a combination of the partial technical solutions from different specific implementations described above, thus achieving the technical effects obtained by the corresponding partial technical solutions. For details regarding the structure and working principle, please refer to the preceding description.

[0075] like Figure 9-10 As shown, as an optional implementation, a slider 222 is also provided between the reservoir 26 and the driving device 3. The slider 222 is an overall annular structure, with its inner and outer annular surfaces slidingly attached to the outer wall of the base tube 1 and the inner wall of the pressure-bearing outer sleeve 4, respectively. Under the drive of the driving device 3, it can move axially inside the reservoir 21, thereby discharging the sealing agent 20 from the reservoir 26.

[0076] Specifically, during the driving process, since the elastic accumulator 360 is in direct contact with the reservoir 26, it may puncture the reservoir 26 or fail to effectively compress it. Therefore, a slider 222 is provided between the elastic accumulator 360 and the reservoir 26. The slider 222 transmits the driving force of the elastic accumulator 360 to the reservoir 26, thereby protecting the reservoir 26 from puncture and more thoroughly discharging the solidifying agent 20 from the reservoir 26 into the wellbore annulus.

[0077] In this embodiment, a technical solution is adopted to store the sealant 20 in the reservoir 26. Users can pre-fill the sealant 20 in the reservoir 26 outside the site, which is convenient for large-scale production, storage and transportation. At the same time, the reservoir 26 with the sealant 20 pre-filled can be used as a component on the construction site, which improves the efficiency of on-site construction.

[0078] Example 5:

[0079] Based on the aforementioned embodiments, this embodiment provides a specific implementation method for a self-driven solid seal pipe section in the annulus of an oil and gas well production section.

[0080] like Figure 11-14 As shown, in an optional embodiment, the inner wall of the pressure-bearing jacket 4 and the outer wall of the base pipe 1 define a pipe section annulus on the side away from the reservoir 21, which also includes an expansion material chamber 46. The axial end of the expansion material chamber 46 away from the reservoir 2 is defined and sealed by the extension fixing part 44 of the end of the pressure-bearing jacket 4 towards the base pipe 1, and the reservoir 2 is connected. The driving device 3 includes an expansion material 36 disposed in the expansion material chamber 46. After the expansion material 36 expands, its volume increases, driving the reservoir 2 to inject the solidifying agent 20 into the wellbore annulus.

[0081] Specifically, the expansion material chamber 46 and the pre-placed expansion material 36 disclosed in this embodiment can be considered as another specific structure of the drive device 3. Its function is the same as the drive device 3 disclosed in the previous embodiment, both providing driving force to inject the solidifying agent 20 into the wellbore annulus. More specifically, as... Figure 11-12 As shown, this is a technical solution that combines the expandable material 36 with the reservoir 26; Figure 13-14 The diagram shows a technical solution that combines the expanding material 36 with the storage tank 21. It is evident that this embodiment combines local technical solutions from different specific implementations described above, thus achieving the technical effects obtained by the corresponding local technical solutions. For details regarding the structure and working principle, please refer to the preceding description.

[0082] like Figure 11-14As shown, in one optional implementation, the expansion material 36 is a liquid-swellable material; the driving device 3 further includes a liquid-swellable control valve 37 disposed on the outer wall of the expansion material chamber 46, the liquid-swellable control valve 37 having a trigger inside for generating an injection trigger signal at a specified time according to user settings; or, the liquid-swellable control valve 37 having a pressure detection device inside for detecting the pressure wave generated by surface filling and generating an injection trigger signal according to the pressure wave; and the liquid-swellable control valve 37 also opens the valve body according to the injection trigger signal to achieve contact between the liquid in the wellbore annulus and the expansion material 36.

[0083] Specifically, the expanding material 36 is a liquid-swellable material that expands upon contact with downhole fluid, thereby driving the solidifying agent 20 to be injected into the wellbore annulus. To achieve contact between the expanding material 36 and the downhole fluid, one or more through-holes are provided on the outer wall of the expanding material chamber 46. A liquid-reacting control valve 37 is installed in each through-hole to allow the fluid in the wellbore to enter the expanding material chamber 46 and contact the expanding material 36. Preferably, the liquid-reacting control valve 37 can employ various control methods: First, the liquid-reacting control valve 37 uses an electronically controlled structure, with a timer as a trigger on the main control circuit board or in the embedded system, and a solenoid valve or other electronically controlled valve as the valve body; second, the liquid-reacting control valve 37 uses a mechanical structure, such as a pressure breaker. The user injects pressure into the wellbore from the ground. When the applied pressure exceeds the breaking pressure of the pressure breaker, it compresses the liquid, allowing it to enter the expansion material chamber 46. Alternatively, the liquid-reactive control valve 37 can be a soluble structure, such as liquid-soluble rubber, with a user-selectable dissolution time (e.g., 8 hours). When the liquid-reactive control valve 37 is lowered into the wellbore and encounters the wellbore liquid, it begins to dissolve. Once the set dissolution time is reached, it no longer obstructs the flow of fluid from the wellbore into the expansion material chamber 46.

[0084] As an optional implementation, the expansion material 36 is a self-expanding material; the initial expansion time of the self-expanding material is 1-24 hours after the self-driven solid seal pipe section is run into the well, and the expansion time of the self-expanding material is 1-48 hours.

[0085] Specifically, the expansion material chamber 46 is a self-expanding material, which is configured and pre-placed by the user on site. After the self-expanding material is run into the well and reaches the initial expansion time, it begins to expand and drives the solidifying agent 20 to be gradually injected into the wellbore annulus. When the expansion time of the self-expanding material is reached, the preset solidifying agent 20 is completely or almost completely injected into the wellbore annulus.

[0086] In this embodiment, by using the expansion material 36 as the component for generating driving force in the driving device 3, its structure is simpler than that of other driving devices 3 mentioned above. It consists of only an expansion material chamber 46 with a shell structure and a single-component expansion material 36. Obviously, it can have a more stable and reliable driving effect, and the cost will be lower.

[0087] Example 6:

[0088] Based on the aforementioned embodiments, this embodiment provides a specific implementation method for a self-driven solid seal pipe section in the annulus of an oil and gas well production section.

[0089] like Figure 15-19 As shown, in one optional embodiment, the number of the storage devices 2 is two; the two storage devices 2 share a single outlet 232, and the outlet 232 is equipped with a sealing agent mixing device 234; each of the two storage devices 2 contains one component of a two-component sealing agent.

[0090] Specifically, due to potential pressure differences between different formations, if the solidification time of the sealing agent 20 is too slow, it will flow slowly under the pressure difference, making it difficult to solidify at the target sealing point. In actual construction, from the injection of the sealing agent 20 into the storage tank 21 to the complete lowering of the central tubing into the wellbore production section, it often takes tens of hours, thus making it impossible to use a sealing agent with a faster solidification time. Therefore, this embodiment presents a technical solution using a two-component sealing agent 20. (See attached document.) Figure 15-19 The storage chamber 21 is axially partitioned by a partition 25, which divides the storage chamber 21 into two independent spaces for containing different components of the first sealing agent 20-1 and the second sealing agent 20-2. Each of the two independent spaces is also equipped with a separate first filling port 231-1, a second filling port 231-2, and a first filling pressure balancing port 353-1 and a second filling pressure balancing port 353-2. Correspondingly, the piston 22 is also divided into two parts, each adapted to one of the two independent spaces. Figure 15-19As shown, the drive device 3 can share a single system, or it can be based on a single control circuit 31 as the main controller, with separate drive motors 33 and / or plunger pumps 34, thereby achieving independent drive and discharge of the two components of the solidifying agent 20. It should be noted that the partition 25 does not necessarily isolate the storage tank 21 into two independent spaces of the same size. The space design can refer to the composition of the two-component solidifying agent; for example, when the ratio of the two components is 1:2, the partition can be set at circumferential 120 degrees and 240 degrees. The advantage of using a two-component system is that the construction process is no longer constrained by the solidifying agent 20's solidification, and work efficiency is improved. For example, when the two components are set independently, they can maintain a fluid state for a longer period (e.g., a month or longer); when the two components are mixed downhole, they can solidify and fix within a shorter time (e.g., 10 minutes to 100 minutes).

[0091] It should be further noted that this embodiment includes... Figure 15-19 This is an improvement based on the accompanying drawings of Embodiment 2. Regarding Embodiments 3-5, those skilled in the art will understand from the textual descriptions and accompanying drawings of these embodiments... Figure 15-19 Under the guidance of this, the technical solutions given in Examples 3-5 can be improved to form technical solutions applicable to the two-component sealing agent 20. These technical solutions are all directly achievable by those skilled in the art and should be considered to fall within the protection scope of this patent.

[0092] Example 7:

[0093] Based on the aforementioned embodiments, this embodiment provides a specific implementation method for a self-driven solidification method for the annulus in the production section of an oil and gas well.

[0094] A self-driven solidification method for the annulus of an oil and gas well production section, using a self-driven solidification tubing section as described in any of Examples 1-6, includes the following steps: (1) prefabricating a self-driven solidification tubing section carrying a solidifying agent 20 onto the central tubing string; wherein the position of the self-driven solidification tubing section relative to the central tubing string corresponds to the position of the target solidification point in the wellbore; (2) running the central tubing string into the wellbore; (3) the driving device driving the storage device to inject the solidifying agent 20 into the wellbore annulus according to the injection trigger signal; (4) the solidifying agent 20 enters the flow pores of the continuous packer in the wellbore annulus and solidifies, forming a solidification body 200 together with the continuous packer, the solidification body 200 being able to prevent the liquid in the wellbore annulus from flowing axially along the wellbore annulus.

[0095] Specifically, the method disclosed in this embodiment uses the apparatus disclosed in Embodiments 1-6. For further method steps and the technical effects achieved, please refer to the description in Embodiments 1-6.

[0096] Example 8:

[0097] Based on the foregoing embodiments, this embodiment provides a specific implementation of a well completion structure.

[0098] like Figure 20-21 As shown, a completion structure is applied to oil and gas wells in a single formation or through multiple formations. The completion structure includes a central tubing string disposed in the production section of the oil and gas well. A wellbore annulus is defined between the wellbore wall of the production section and the central tubing string. A continuous packer formed by the accumulation of packing particles is disposed in the wellbore annulus. The central tubing string is characterized in that it includes a self-driven solid seal section 5 as described in any of Examples 1-6.

[0099] Specifically, such as Figure 20 The image shows the state of the self-driven solidification tube section 5 when it is run into the wellbore production section and the solidification agent 5 has not yet been discharged; as shown... Figure 21 The figure shows the state of the self-driven solidification section 5 after the solidification agent 5 is discharged. As can be seen from the figure, the solidification agent 5 forms a solidification body 200 in the wellbore annulus.

[0100] The well completion structure disclosed in this embodiment adopts the device disclosed in Embodiments 1-6. For further structure and technical effects, please refer to the description in Embodiments 1-6.

[0101] The above description, in conjunction with specific preferred embodiments, provides a further detailed explanation of the present invention. It should not be construed that the specific implementation of the present invention is limited to these descriptions. For those skilled in the art, various simple deductions or substitutions can be made without departing from the concept of the present invention, and all such modifications and substitutions should be considered within the protection scope of the present invention.

Claims

1. A self-driven solidified sealing tubing joint for the annulus of an oil and gas well production section, applied in oil and gas wells with a single formation or penetrating multiple formations, wherein a central tubing string is provided in the production section wellbore, and an annulus is defined between the wellbore wall of the production section wellbore and the central tubing string, and a continuous packer formed by the accumulation of packing particles is provided in the annulus; characterized in that, The central tubing column includes the self-driven solidified tubing section, which includes: The base tube has an overall tubular structure with docking devices at both ends, which can be connected end-to-end with adjacent tube sections in the central tube column. A storage device is installed on the base pipe. The storage device contains a solidifying agent. Under external driving action, the storage device can inject the solidifying agent into the wellbore annulus. The solidifying agent can enter the flow pores of the continuous packer and solidify, forming a solid seal together with the continuous packer. The solid seal can prevent the liquid in the wellbore annulus from flowing axially along the wellbore annulus. A drive unit, mounted on the base pipe, is used to drive the reservoir device to inject the solidifying agent into the wellbore annulus according to the injection trigger signal.

2. The self-driven solid seal pipe section for the annulus of the oil and gas well production section according to claim 1, characterized in that: The injection trigger signal is generated by a trigger located inside the drive device.

3. The self-driven solid seal pipe section for the annulus of the oil and gas well production section according to claim 2, characterized in that: It also includes a pressure-bearing jacket, which is a cylindrical structure and is disposed on the outside of the base pipe; the storage device and the driving device are disposed in the annular space formed by the inner wall of the pressure-bearing jacket and the outer wall of the base pipe.

4. The self-driven solid seal pipe section for the annulus of the oil and gas well production section according to claim 3, characterized in that: The storage device includes a storage chamber defined by a portion of the inner wall of the pressure-bearing jacket and a portion of the outer wall of the base tube. A piston is located at one end of the storage chamber near the drive device, and a dispensing connector is located at the other end. The piston is an integral ring structure, with its inner and outer ring surfaces slidingly sealing against the outer wall of the base tube and the inner wall of the pressure-bearing jacket, respectively. It can move axially inside the storage tank under the drive of external force. The dispensing connector connects and fixes the end of the pressure-bearing outer jacket to the base pipe and seals the end of the storage chamber; the dispensing connector is provided with a filling port and a dispensing port inside, which are used to fill the solidifying agent into the storage chamber and to discharge the solidifying agent from the storage chamber, respectively.

5. The self-driven solid seal pipe section for the annulus of the oil and gas well production section according to claim 4, characterized in that: The drive unit includes a control circuit, a battery, a drive motor, and a plunger pump, wherein... The control circuit is equipped with a trigger to generate an injection trigger signal at a specified time according to user settings; or, the control circuit is equipped with a pressure detection device to detect the pressure wave generated by ground filling and generate an injection trigger signal based on the pressure wave; and the control circuit also controls the drive motor to operate according to the injection trigger signal. The battery is used to power the control circuit; The drive motor is used to receive control from the control circuit and drive the plunger pump to operate; The plunger pump is driven by the drive motor to inject the liquid in the wellbore annulus into the sealed pressure space on the side of the piston away from the outlet joint, driving the piston to move towards the outlet joint, thereby discharging the solidifying agent in the storage tank through the outlet.

6. The self-driven solid seal pipe section for the annulus of the oil and gas well production section according to claim 5, characterized in that: The drive device further includes a liquid inlet connector, which is fixedly and sealed to the annulus of the pipe section. The liquid inlet connector, the piston, the inner wall of the pressure-bearing jacket, and the outer wall of the base pipe define a sealed pressure space. The liquid inlet connector internally provides a plunger pump inlet channel and a plunger pump outlet channel. The plunger pump inlet channel connects the plunger pump inlet and the wellbore annulus; The plunger pump outlet channel connects the plunger pump outlet and the sealed pressure space.

7. The self-driven solid seal pipe section for the annulus of the production section of an oil and gas well according to claim 6, characterized in that: The inner wall of the pressure-bearing jacket and the outer wall of the base pipe define a pipe section annulus on the side opposite to the storage tank, which also includes an electrical control compartment and an electric control compartment. The axial ends of the electrical control compartment and the electric control compartment are defined and sealed by the extension and fixing portion of the pressure-bearing jacket towards the base pipe, and by the liquid inlet connector. The electrical control compartment is used to house the control circuit and the battery that supplies power to the control circuit; The electric compartment is used to house the drive motor and the plunger pump.

8. The self-driven solid seal pipe section for the annulus of the production section of an oil and gas well according to claim 4, characterized in that: The driving device includes an elastic energy storage device, a limiting device, a controller, and a release device, wherein... The controller is equipped with a trigger, which generates an injection trigger signal at a specified time according to user settings, and controls the releaser to release the limiting device according to the injection trigger signal; The release device is used to receive control from the controller and release the limiting device; One end of the elastic storage device is fixed, and the other end is a free end, with the free end extending in the direction of the piston. The elastic storage device is in a compressed state in the initial state, and its extension is restricted by the limiting device. When the limiting device is released by the release device, the free end of the elastic storage device extends outward and drives the piston to move in the direction of the dispensing connector, thereby discharging the solidifying agent in the storage tank through the dispensing port.

9. The self-driven solid seal pipe section for the annulus of the production section of an oil and gas well according to claim 8, characterized in that: The triggers set in the controller are either electronic timers or mechanical timers.

10. The self-driven solid seal pipe section for the annulus of the production section of an oil and gas well according to claim 8, characterized in that: The inner wall of the pressure-bearing jacket and the outer wall of the base pipe define a pipe section annulus that is away from the storage tank. The side of the annulus opposite to the storage tank also includes an elastic drive device compartment. The axial ends of the elastic drive device compartment are defined and sealed by the extension and fixing part of the pressure-bearing jacket end to the base pipe and the liquid inlet joint. The elastic energy storage device, the limiting device, the controller and the release device are disposed in the elastic drive device compartment.

11. The self-driven solid seal pipe section for the annulus of the production section of an oil and gas well according to claim 8, characterized in that: The elastic energy storage device is a spring structure.

12. The self-driven solid seal pipe section for the annulus of the production section of an oil and gas well according to claim 3, characterized in that: The storage device is a storage bladder, which is disposed in a storage chamber defined by a portion of the inner wall of the pressure-bearing jacket and a portion of the outer wall of the base tube. The opening of the storage bladder is connected to a dispensing connector. The dispensing connector connects and fixes the end of the pressure-bearing jacket to the base tube and seals the end of the storage chamber. The dispensing connector has a dispensing port inside for discharging the sealing agent from the storage bladder.

13. The self-driven solid seal pipe section for the annulus of the production section of an oil and gas well according to claim 12, characterized in that: The driving device includes a control circuit, a drive motor, and a piston pump, wherein, The control circuit is equipped with a trigger to generate an injection trigger signal at a specified time according to user settings; or, the control circuit is equipped with a pressure detection device to detect the pressure wave generated by ground filling and generate an injection trigger signal based on the pressure wave; and the control circuit also controls the drive motor to operate according to the injection trigger signal. The drive motor is used to receive control from the control circuit and drive the plunger pump to operate; The plunger pump is driven by the drive motor to inject the liquid in the wellbore annulus into the reservoir, thereby discharging the solidifying agent in the reservoir through the outlet.

14. The self-driven solid seal pipe section for the annulus of the production section of an oil and gas well according to claim 12, characterized in that: The driving device includes an elastic energy storage device, a limiting device, a controller, and a release device, wherein... The controller is equipped with a trigger, which generates an injection trigger signal at a specified time according to user settings, and controls the releaser to release the limiting device according to the injection trigger signal; The release device is used to receive control from the controller and release the limiting device; One end of the elastic storage device is fixed, and the other end is a free end, with the free end extending in the direction of the reservoir. The elastic storage device is in a compressed state in the initial state, and its extension is restricted by the limiting device. When the limiting device is released by the release device, the free end of the elastic storage device extends toward the reservoir and squeezes the reservoir, thereby discharging the sealing agent in the reservoir through the outlet.

15. The self-driven solid seal pipe section for the annulus of the production section of an oil and gas well according to claim 12, characterized in that: A slider is also provided between the reservoir and the driving device. The slider is an overall annular structure, with its inner and outer annular surfaces slidingly fitting against the outer wall of the base tube and the inner wall of the pressure-bearing jacket, respectively. Under the drive of the driving device, it can move axially inside the reservoir, thereby discharging the sealing agent from the reservoir.

16. The self-driven solidified sealing pipe section for the annulus of the production section of an oil and gas well according to claim 4 or 12, characterized in that: The annulus formed by the inner wall of the pressure-bearing jacket and the outer wall of the base pipe also includes an expansion material chamber on the side opposite to the reservoir. The end of the expansion material chamber facing away from the reservoir is defined and sealed by the extension fixed part of the pressure-bearing jacket towards the base pipe, and the reservoir is connected. The driving device includes expansion material disposed in the expansion material chamber. After the expansion material expands, its volume increases, driving the reservoir to inject the solidifying agent into the wellbore annulus.

17. The self-driven solid seal pipe section for the annulus of the production section of an oil and gas well according to claim 16, characterized in that: The expanding material is a liquid-swellable material; the driving device further includes a liquid-swellable control valve disposed on the outer wall of the expanding material chamber, wherein the liquid-swellable control valve is equipped with a trigger for generating an injection trigger signal at a specified time according to user settings; or, the liquid-swellable control valve is equipped with a pressure detection device for detecting the pressure wave generated by surface filling and generating an injection trigger signal according to the pressure wave; and the liquid-swellable control valve also opens the valve body according to the injection trigger signal to achieve contact between the liquid in the wellbore annulus and the expanding material.

18. The self-driven solid seal pipe section for the annulus of the production section of an oil and gas well according to claim 16, characterized in that: The expansion material is a self-expanding material; the initial expansion time of the self-expanding material is 1-24 hours after the self-driven solid seal pipe section is run into the well, and the expansion time of the self-expanding material is 1-48 hours.

19. The self-driven solidified sealing pipe section for the annulus of the production section of an oil and gas well according to any one of claims 1 to 15, 17 or 18, characterized in that: The number of the storage devices is two; the two storage devices share a single outlet, and the outlet is equipped with a sealing agent mixing device; each of the two storage devices contains one component of a two-component sealing agent.

20. The self-driven solid seal pipe section for the annulus of the production section of an oil and gas well according to claim 16, characterized in that: The number of the storage devices is two; the two storage devices share a single outlet, and the outlet is equipped with a sealing agent mixing device; each of the two storage devices contains one component of a two-component sealing agent.

21. A completion structure, applied in oil and gas wells in a single formation or penetrating multiple formations, the completion structure comprising a central tubing string disposed in the production section of the oil and gas wellbore, wherein a wellbore annulus is defined between the wellbore wall of the production section and the central tubing string, and a continuous packer formed by the accumulation of packing particles is disposed in the wellbore annulus; characterized in that, The central tubing includes the self-driven solidified tubing section as described in any one of claims 1 to 20.

Images