A tubing-communicating downhole gas release tool

Abstract

The application provides a tubing communication type downhole gas release tool, relates to the technical field of downhole tools in the oil and gas industry, and comprises a tubing body and a gas exhaust control mechanism, the tubing body is provided with a main oil and gas transportation channel, a hydraulic control cavity and a gas exhaust hole, the hydraulic control cavity is communicated with the main oil and gas transportation channel and the gas exhaust hole respectively, and the gas exhaust control mechanism is arranged in the hydraulic control cavity; the gas exhaust control mechanism is connected with a ground hydraulic control station, the gas exhaust hole is communicated with a downhole packer, in an initial state, the gas exhaust hole is not communicated with the main oil and gas transportation channel, and in a working state, the gas exhaust hole is communicated with the main oil and gas transportation channel; the tubing communication type downhole gas release tool in the application effectively divides the packer and the gas exhaust valve into two separate products, so that the packer is separated from the limitation of the gas exhaust valve, the safety of downhole gas exhaust is improved, and the problem that the gas exhaust hole of the packer is blocked due to impurity deposition in the upper annular space of the packer is solved.

Description

Technical Field

[0001] This invention relates to the field of downhole tool technology in the oil and gas industry, and more specifically, to a tubing-connected downhole gas release tool. Background Technology

[0002] During well completion operations, a large amount of gas often accumulates continuously at the bottom of the already set ESP packer (electric submersible pump packer). At this time, a venting valve is needed to release this gas to prevent it from accumulating more and more, increasing the pressure, and causing damage to the ESP packer or mis-sealing, thereby causing unnecessary accidents or well workover operations.

[0003] The widely used venting valve can be considered as a sub-assembly installed on the ESP packer. The opening and closing of the venting valve is controlled by the surface hydraulic station. As the packer is lowered into the formation, the pressure of opening and closing the venting valve decreases. At a certain well depth, the venting valve is no longer controlled by the surface hydraulic station and remains in a normally open state, which poses a great hidden danger to subsequent operations. Therefore, the existing venting valve restricts the depth of the packer.

[0004] Due to formation pressure and temperature issues, the closer to the surface, the lower the formation pressure and temperature. Packers are prone to problems such as waxing and freezing, which can lead to difficulties in recovering the packers during well workover and unpacking. At the same time, the packers are far from the oil and gas layer, meaning they are shallowly installed, which is not conducive to efficient oil and gas extraction. Therefore, how to install packers into deeper formations has become a challenge in well completion operations.

[0005] The conventional venting valve works by having the surface hydraulic station control the opening of the venting valve to release the gas accumulated in the ESP packer into the upper annular space. The gas is then diverted to another location for release or combustion via the venting bypass line of the wellhead. If venting is not timely, or if there is a sudden surge in gas, excessive accumulation in the annular space can put significant pressure on the wellhead's Christmas tree, burdening surface equipment and posing a major safety hazard. If the Christmas tree fails, there will be no safety devices available, and a large amount of gas will erupt to the surface, causing personal injury and property damage.

[0006] The vent of a regular vent valve is located at the bottom. Impurities in the annular space above the ESP packer can easily clog the vent, thus preventing the venting function from being realized.

[0007] In summary, existing venting valves have the following defects:

[0008] 1. The vent valve limits the insertion depth of the ESP packer;

[0009] 2. Relying on the wellhead for processing emitted gases poses significant safety hazards;

[0010] 3. Deposits of impurities in the gas can easily lead to blockage of the exhaust port. Summary of the Invention

[0011] To address the shortcomings of existing technologies, this application provides a downhole gas release tool with tubing connection.

[0012] This application discloses a tubing-connected downhole gas release tool comprising: a tubing body and an exhaust control mechanism. The tubing body has a main oil and gas transport channel, a hydraulic control chamber, and an exhaust port. The hydraulic control chamber is connected to both the main oil and gas transport channel and the exhaust port. The exhaust control mechanism is located within the hydraulic control chamber. In the initial state, the exhaust port is not connected to the main oil and gas transport channel. In the working state, the exhaust port is connected to the main oil and gas transport channel.

[0013] Preferably, the oil pipe body is provided with a first connecting hole and a second connecting hole, and the hydraulic control chamber has an upper end and a lower end. The upper end is located above the gravity direction of the hydraulic control chamber, and the lower end is located below the gravity direction of the hydraulic control chamber. The second connecting hole is disposed opposite to the lower end, and the first connecting hole is disposed between the upper end and the lower end. The first connecting hole connects to the exhaust hole and the hydraulic control chamber, and the second connecting hole connects to the main oil and gas transport channel and the hydraulic control chamber.

[0014] Preferably, the exhaust control mechanism includes a sleeve, a spindle assembly, a sealing assembly, and a reset assembly; the sleeve is fixedly disposed within the hydraulic control chamber, and a first through hole is provided on the peripheral wall of the sleeve; the spindle assembly includes an exhaust spindle and a sealing piston, the exhaust spindle is disposed within the sleeve, and the sealing piston is sleeved on the exhaust spindle and slidably connected to the sleeve; the sealing assembly includes a first spacer ring, a second spacer ring, and a third spacer ring, the first spacer ring is located at the end of the sealing piston facing away from the second connecting hole, it is sleeved on the exhaust spindle and fixedly connected to the inner wall of the sleeve, the second spacer ring is located at one end of the first connecting hole, it is sealed to the sleeve and the cavity wall of the hydraulic control chamber respectively, and the third spacer ring is located at the other end of the first connecting hole, it is sealed to the sleeve and the cavity wall of the hydraulic control chamber respectively, and the second and third spacer rings are located at opposite ends of the first through hole respectively; the reset assembly is disposed within the sleeve and is connected to the exhaust spindle; in the initial state, the sealing piston blocks the first through hole, and the exhaust hole is not connected to the main oil and gas transport channel; in the working state, the sealing piston leaves the first through hole, and the exhaust hole is connected to the main oil and gas transport channel.

[0015] Preferably, the exhaust mandrel peripheral wall is provided with a second through hole, which is located between the first spacer ring and the sealing piston.

[0016] Preferably, the reset assembly includes a limiting seat, a limiting block, and an elastic element. The limiting seat is located on the side of the first spacer ring facing away from the sealing piston and is fixedly connected to the exhaust mandrel. The limiting block is located between the limiting seat and the first spacer ring and is engaged with the limiting seat. The elastic element is located between the limiting block and the first spacer ring, with one end abutting against the limiting block and the other end abutting against the first spacer ring.

[0017] Preferably, the outer wall ring of the exhaust mandrel is provided with a groove, the limiting seat is provided in the groove, the limiting block has an abutting part and a locking part, the abutting part abuts against the elastic element, and the locking part is located between the limiting seat and the first spacer ring and locking with the limiting seat.

[0018] Preferably, the reset assembly further includes a top nut, which is disposed inside the sleeve and located at the end of the limiting seat facing away from the first spacer ring, and the diameter of its inner wall surface is smaller than the outer diameter of the limiting block.

[0019] Preferably, the reset assembly further includes a lower plug, which is disposed inside the sleeve and located at the end of the sealing piston facing away from the first spacer ring, and the diameter of its inner wall surface is smaller than the outer diameter of the sealing piston.

[0020] Preferably, the reset assembly further includes a base, which is disposed on the first spacer ring and located between the first spacer ring and the elastic member. One end of the elastic member abuts against the base, and the other end abuts against the limiting block.

[0021] Preferably, the vent is connected to the packer via a rigid conduit with a 3 / 8" NPT thread.

[0022] The beneficial effects of this application are as follows: By using the tubing-connected downhole gas release tool of this application, the packer and the tubing-connected downhole gas release tool are effectively separated into two separate products, making the packer and the tubing-connected downhole gas release tool completely independent. Thus, the packer is freed from the limitations of the tubing-connected downhole gas release tool, and the packer can be placed in deeper formations downhole, solving other interlocking problems. Gas is transported from the packer, which is far from the wellhead, to the tubing-connected downhole gas release tool, which is closer to the wellhead, through a longer gas pipeline. The gas is then transported to the inside of the tubing through the tubing-connected downhole gas release tool, thereby releasing the gas accumulated below the packer.

[0023] The tubing-connected downhole gas release tool guides the gas accumulated below the packer into the main tubing. Since the oil and gas recovered from the main tubing undergoes oil and gas separation in specialized equipment on the surface, this product re-aggregates the accumulated gas with the oil and gas in the main tubing and then enters the specialized equipment for oil and gas separation. This not only ensures the venting needs without increasing additional costs, but also eliminates the need to treat the released gas through the wellhead, improving the safety of downhole operations.

[0024] The tubing-connected downhole gas release tool is located at the top of the packer. It utilizes the principle that gas is lighter to ensure that gas is released from bottom to top, and the channel connected to the main tubing is in a relatively closed environment. This completely solves the problem of the packer vent being blocked due to the deposition of impurities in the annular space above the packer. Attached Figure Description

[0025] The accompanying drawings, which are included to provide a further understanding of this application and form part of this application, illustrate exemplary embodiments of this application and are used to explain this application, but do not constitute an undue limitation of this application. In the drawings:

[0026] Figure 1 These are schematic diagrams of the tubing-connected downhole gas release tool from different perspectives in the embodiments.

[0027] Figure 2 The figures show a top view and a bottom view of the tubing-connected downhole gas release tool in the embodiment.

[0028] Figure 3 This is a perspective view of the downhole gas release tool with tubing connection in the embodiment;

[0029] Figure 4 This is a cross-sectional view of the tubing-connected downhole gas release tool in the embodiment;

[0030] Figure 5 This is a cross-sectional view of the exhaust control mechanism in its initial state in the embodiment;

[0031] Figure 6 This is a cross-sectional view of the exhaust control mechanism in operation during the embodiment.

[0032] Figure 7 This is a schematic diagram of the gas flow direction of the tubing-connected downhole gas release tool in the embodiment;

[0033] Figure 8 This is a schematic diagram of the drive shaft structure in the embodiment;

[0034] Figure 9 This is a schematic diagram of the limiting block structure in the embodiment.

[0035] Figure label:

[0036] 1-Oil pipe body; 2-Exhaust control mechanism;

[0037] 11-Main oil and gas transport channel; 12-Hydraulic control chamber; 13-Exhaust port; 14-First connection hole; 15-Second connection hole;

[0038] 21-Sleeve; 22-Mandrel assembly; 23-Sealing assembly; 24-Reset assembly;

[0039] 121 - Upper end; 122 - Lower end;

[0040] 211 - First through hole;

[0041] 221 - Exhaust mandrel; 222 - Sealing piston;

[0042] 231 - First spacer ring; 232 - Second spacer ring; 233 - Third spacer ring;

[0043] 241-Limit seat; 242-Limit block; 243-Elastic element; 244-Top nut; 245-Lower plug; 246-Base; 247-Spring sleeve;

[0044] 2211 - Second through hole; 2212 - Groove;

[0045] 2421 - Abutting part; 2422 - Snap-fitting part. Detailed Implementation

[0046] The following drawings disclose several embodiments of this application. For clarity, many practical details will be described in the following description. However, it should be understood that these practical details should not be used to limit this application. That is, in some embodiments of this application, these practical details are not essential. In addition, for the sake of simplicity, some conventional structures and components will be shown in the drawings in a simple schematic manner.

[0047] It should be noted that all directional indications in the embodiments of this application, such as up, down, left, right, front, back, etc., are only used to explain the relative positional relationship and movement of the components in a specific posture as shown in the attached figure. If the specific posture changes, the directional indication will also change accordingly.

[0048] Furthermore, the use of terms such as "first" and "second" in this application is for descriptive purposes only and does not specifically refer to any order or sequence, nor is it intended to limit this application. They are merely used to distinguish components or operations described using the same technical terms and should not be construed as indicating or implying relative importance or implicitly specifying the number of indicated technical features. Therefore, a feature defined with "first" or "second" may explicitly or implicitly include at least one of those features. Additionally, the technical solutions of various embodiments can be combined with each other, but only if they are feasible for those skilled in the art. If a combination of technical solutions is contradictory or impossible to implement, it should be considered that such a combination of technical solutions does not exist and is not within the scope of protection claimed in this application.

[0049] To further understand the content, features, and effects of this application, the following embodiments are provided, and detailed descriptions are given in conjunction with the accompanying drawings.

[0050] Please see Figures 1 to 8 In this example, the tubing-connected downhole gas release tool is used to discharge the gas accumulated below the packer to the outside of the well. It includes a tubing body 1 and an exhaust control mechanism 2. The tubing body 1 has an oil and gas main transport channel 11, a hydraulic control chamber 12 and an exhaust port 13. The oil and gas main transport channel 11 is connected to the tubing to establish a conventional oil and gas transport channel. The exhaust port 13 is connected to the packer in a deeper formation through a rigid pipeline. The exhaust control mechanism 2 in the hydraulic control chamber 12 is connected to the hydraulic station at the wellhead through a rigid pipeline.

[0051] See Figure 1 , Figure 2 and Figure 3 The main oil and gas transport channel 11, hydraulic control chamber 12, and vent 13 are all eccentric structures on the oil pipe body 1, and all three are arranged along the length of the oil pipe body 1. The main oil and gas transport channel 11 is the main oil and gas transport channel connecting the oil pipe. The hydraulic control chamber 12 is formed by a partially drilled hole on the oil pipe body 1, which connects the main oil and gas transport channel 11 and the vent 13. The vent control mechanism 2 is located in the hydraulic control chamber 12 and controls the opening and closing of the vent function. The vent 13 is also a partially drilled hole, and it is connected to the packer through a connecting tool. This connecting tool can be a long gas pipeline or a rigid pipeline. Gas accumulated at the bottom of the packer can enter the vent 13 through the gas pipeline or rigid pipeline. Inside the well, the exhaust control mechanism 2 is connected to the hydraulic control station on the ground via a connecting tool, which can be a gas pipeline or a rigid pipeline. The hydraulic control station controls the opening and closing of the exhaust control mechanism 2 by pressure changes. In the initial state, the exhaust control mechanism 2 is in the closed state, and the exhaust port 13 is not connected to the main oil and gas transport channel 11. The gas emitted by the downhole packer cannot be discharged through the exhaust port 13. In the working state, the exhaust control mechanism 2 is in the open state, and the exhaust port 13 is connected to the main oil and gas transport channel 11. The gas accumulated under the packer and the oil and gas in the main oil and gas transport channel 11 converge. The gas is discharged out of the well along with the oil and gas in the main oil and gas transport channel 11 and enters the dedicated oil and gas treatment equipment for oil and gas separation.

[0052] Thus, by using the tubing-connected downhole gas release tool of this application, the packer and the tubing-connected downhole gas release tool are effectively separated into two separate products, making the packer and the tubing-connected downhole gas release tool completely independent. This allows the packer to be freed from the restriction of the vent valve, and the packer can be placed in deeper formations downhole, solving other interlocking problems. Gas is transported from the packer, which is far from the wellhead, to the tubing-connected downhole gas release tool, which is closer to the wellhead, through a longer gas pipeline. The gas is then transported into the tubing through the tubing-connected downhole gas release tool, thereby releasing the gas accumulated under the packer.

[0053] The tubing-connected downhole gas release tool guides the gas accumulated below the packer into the main oil and gas transport channel 11. Since the oil and gas harvested from the main oil and gas transport channel 11 will be separated in the dedicated equipment on the surface, this product will re-aggregate the accumulated gas with the oil and gas and then enter the dedicated equipment for oil and gas separation. This not only ensures the venting needs without increasing additional costs, but also eliminates the need to treat the vented gas through the wellhead, thus improving downhole safety.

[0054] The tubing-connected downhole gas release tool is located at the top of the packer. It utilizes the principle that gas is lighter to ensure that gas is released from bottom to top, and the channel connected to the main tubing is in a relatively closed environment. This completely solves the problem of the packer vent being blocked due to the deposition of impurities in the annular space above the packer.

[0055] See also Figure 4 Furthermore, the oil pipe body 1 is provided with a first connecting hole 14 and a second connecting hole 15. The hydraulic control chamber 12 has an upper end 121 and a lower end 122. The upper end 121 is located above the gravity direction of the hydraulic control chamber 12, and the lower end 122 is located below the gravity direction of the hydraulic control chamber 12, that is, at the bottom of the hydraulic control chamber 12. The second connecting hole 15 is provided relative to the lower end 122 of the hydraulic control chamber 12. The first connecting hole 14 is provided between the upper end 121 and the lower end 122. The first connecting hole 14 connects the exhaust hole 13 and the hydraulic control chamber 12, and the second connecting hole 15 connects the main oil and gas transport channel 11 and the hydraulic control chamber 12.

[0056] Specifically, the hydraulic control chamber 12 is located at one end of the tubing body 1, and the vent 13 is located at the other end of the tubing body 1. The first connecting hole 14 connects the vent 13 and the hydraulic control chamber 12. Gas enters the hydraulic control chamber 12 through the vent 13 via the first connecting hole 14. The second connecting hole 15 connects the main oil and gas transport channel 11 and the hydraulic control chamber 12. Gas enters the main oil and gas transport channel 11 through the hydraulic control chamber 12 via the second connecting hole 15. In the working state of the tubing-connected downhole gas release tool, the gas released from the packer flows through the hard pipeline to the vent 13, then flows through the vent 13 through the first connecting hole 14 into the hydraulic control chamber 12, and then flows through the hydraulic control chamber 12 through the second connecting hole 15 into the main oil and gas transport channel 11. That is, according to the flow direction of the gas discharged from the packer, the gas flows sequentially through the vent 13, the first connecting hole 14, the hydraulic control chamber 12, the second connecting hole 15, and the main oil and gas transport channel 11.

[0057] See also Figure 5 , Figure 6 and Figure 7Furthermore, the exhaust control mechanism 2 includes a sleeve 21, a spindle assembly 22, a sealing assembly 23, and a reset assembly 24. The sleeve 21 is fixed in the hydraulic control chamber 12, and the sleeve 21 has a first through hole 211 on its peripheral wall.

[0058] The spindle assembly 22 includes an exhaust spindle 221 and a sealing piston 222. The exhaust spindle 221 is disposed inside the sleeve 21, and the sealing piston 222 is sleeved on the exhaust spindle 221. The length of the sealing piston 222 is less than the length of the exhaust spindle 221. The sealing piston 222 is fixedly connected to the exhaust spindle 221, and the sealing piston 222 is also slidably connected to the inner wall of the sleeve 21.

[0059] The sealing assembly 23 includes a first spacer 231, a second spacer 232, and a third spacer 233. The first spacer 231 is located at the end of the sealing piston 222 facing away from the second connecting hole 15. The first spacer 231 is sleeved on the exhaust mandrel 221 and fixedly connected to the inner wall of the sleeve 21. The exhaust mandrel 221 is slidably connected to the first spacer 231. The second spacer 232 is located at one end of the first connecting hole 14. Its inner wall abuts against the sleeve 21, and its outer wall abuts against the cavity wall of the hydraulic control chamber 12. The third spacer 233... Located at the other end of the first connecting hole 14, its inner wall abuts against the sleeve 21, and its outer wall abuts against the cavity wall of the hydraulic control cavity 12. The second spacer ring 232 and the third spacer ring 233 are located at opposite ends of the first through hole 211, respectively. The first spacer ring 231 is sealed to the exhaust mandrel 221 and the sleeve 21. The second spacer ring 232 is sealed to the sleeve 21 and the cavity wall of the hydraulic control cavity 12. The third spacer ring 233 is sealed to the sleeve 21 and the cavity wall of the hydraulic control cavity 12.

[0060] In application, the sleeve 21 is connected to the ground hydraulic control station. The hydraulic control station controls the movement of the exhaust mandrel 221 within the sleeve 21 through pressure changes. The exhaust mandrel 221 drives the sealing piston 222 to move. The sealing piston 222 is slidably connected to the sleeve 21 and maintains a seal. Initially, the sealing piston 222 is located at the first through hole 211 and blocks the first through hole 211. With the first through hole 211 blocked, gas in the vent hole 13 cannot enter the main oil and gas transport channel 11. Later, when it is necessary to remove the gas accumulated at the bottom of the packer, the surface hydraulic control station pressurizes the sleeve 21 through the gas pipeline. When the pressure reaches the preset opening pressure, the tubing-connected downhole gas release tool opens, and the vent spindle 221 moves within the sleeve 21. The vent spindle 221 drives the sealing piston 222 and the reset assembly 24 to move together, that is, the spindle assembly 22 moves within the sleeve 21. When the sealing piston 222 moves to a position where it no longer completely blocks the first through hole 211, the tubing-connected downhole gas release tool... When in operation, the gas in the vent hole 13 enters the vent mandrel 221 through the first through hole 211, enters the main oil and gas transport channel 11 through the second connecting hole 15, and returns to the surface along with the fluid in the main oil and gas transport channel 11. That is, the gas in the vent hole 13 flows sequentially through the first through hole 211, the vent mandrel 221, the second connecting hole 15, and the main transport channel 11. When venting is not required, the pressure acting on the sleeve 21 is released using the ground hydraulic control station. The reset assembly 24 resets the vent mandrel 221, and the vent mandrel 221 drives the sealing piston 222 to reset together. That is, the mandrel assembly 22 is reset, and the sealing piston 222 re-seals the first through hole 211, thereby closing the downhole gas release tool connected to the tubing and stopping the packer from venting.

[0061] Furthermore, the exhaust mandrel 221 has a second through hole 2211 on its peripheral wall, which is located between the first spacer ring 231 and the sealing piston 222.

[0062] The exhaust mandrel 221 is provided with a second through hole 2211, which can increase the gas flow rate entering the exhaust mandrel 221 from the exhaust hole 13 and improve the exhaust speed of the packer. When the exhaust mandrel 221 moves, it drives the second through hole 2211 to move to the position opposite to the first through hole 211, and the gas flow rate is optimal.

[0063] Furthermore, the reset assembly 24 includes a limiting seat 241, a limiting block 242, and an elastic element 243. The limiting seat 241 is located on the side of the first spacer ring 231 facing away from the sealing piston 222 and is fixedly connected to the exhaust spindle 221. The limiting block 242 is located between the limiting seat 241 and the first spacer ring 231 and is engaged with the limiting seat 241. The elastic element 243 is located between the limiting block 242 and the first spacer ring 231, with one end abutting against the limiting block 242 and the other end abutting against the first spacer ring 231.

[0064] After the ground hydraulic control station pressurizes the sleeve 21 through the air pipeline, the exhaust spindle 221 moves, and the limiting seat 241 and the limiting block 242 move synchronously with the exhaust spindle 221. When the pressure reaches the preset opening pressure, the elastic element 243 is compressed by the limiting seat 241 and the first spacer ring 231. After the pressure acting on the sleeve 21 is released by the ground hydraulic control station, the elastic element 243 pushes the limiting block 242 to reset under the action of the rebound force. The limiting block 242 drives the limiting seat 241 and the exhaust spindle 221 to reset. The exhaust spindle 221 drives the sealing piston 222 to seal to the first through hole 211.

[0065] See also Figure 8 and Figure 9 Furthermore, the outer wall of the exhaust mandrel 221 is provided with a groove 2212, the limiting seat 241 is disposed in the groove 2212 and is engaged with the groove wall of the groove 2212, and the outer diameter of the limiting seat 241 is larger than the outer diameter of the outer wall of the exhaust mandrel 221. The limiting block 242 has an abutment part 2421 and a locking part 2422. The abutment part 2421 is disposed around the limiting seat 241 and abuts against the elastic member 243. The locking part 2422 is located between the limiting seat 241 and the first spacer ring 231 and is engaged with the limiting seat 241.

[0066] Furthermore, the reset assembly 24 also includes a top nut 244, which is located inside the sleeve 21 and at one end of the limiting seat 241 facing away from the first spacer ring 231. The diameter of its inner wall surface is smaller than the outer diameter of the limiting block 242.

[0067] The top nut 244 is fixed inside the sleeve 21 and is connected to the sleeve 21 by threads. The top nut 244 restricts the position of the mandrel assembly 22 and ensures that the elastic element 243 has a certain pre-pressure in the initial state of the tubing-connected downhole gas release tool. This ensures that after the pressure is released from the surface hydraulic control station, the reset component 24 will restore the mandrel assembly 22 to the fully closed state.

[0068] Furthermore, the reset assembly 24 also includes a lower plug 245, which is disposed inside the sleeve 21 and located at the end of the sealing piston 222 facing away from the first spacer ring 231, and its inner wall diameter is smaller than the outer diameter of the sealing piston 222.

[0069] The lower plug 245 is fixed inside the sleeve 21 and is connected to the sleeve 21 by threads. The lower plug 245 is used to limit the movement of the spindle assembly 22 and prevent the elastic element 243 from overload and failing.

[0070] Furthermore, the reset assembly 24 also includes a base 246, which is disposed on the first spacer ring 231 and located between the first spacer ring 231 and the elastic member 243. One end of the elastic member 243 abuts against the base 246, and the other end abuts against the limiting block 242.

[0071] The base 246 is used to protect the first spacer ring 231 and prevent the elastic element 243 from damaging the first spacer ring 231.

[0072] Furthermore, the reset assembly 24 also includes a spring sleeve 247, which is disposed inside the sleeve 21 and located between the top nut 244 and the first spacer ring 231. The limiting seat 241, the limiting block 242 and the elastic element 243 are all located inside the spring sleeve 247. The inner wall of the first spacer ring 231 is sealed to the exhaust mandrel 211, and the outer wall is sealed to the spring sleeve 247.

[0073] Thus, when the tubing-connected downhole gas release tool is in operation, the first spacer ring 231 can block the gas entering the sleeve 21 through the first connection hole 14, thereby reducing the wear and corrosion of the elastic element 243 and extending the service life of the elastic element 243.

[0074] Furthermore, the vent 13 is connected to the packer via a rigid conduit with a 3 / 8" NPT thread.

[0075] In application, a conventional vent valve is directly connected to the packer, which to some extent restricts the design space of the packer and makes it impossible to meet the construction requirements. The product of this application uses a rigid pipeline that occupies less space. The outer diameter of the pipeline connecting the vent valve and the packer is 3 / 8", which is much smaller than that of a conventional vent valve (which uses an outer diameter of 1.5"), thus ensuring that the packer can be designed with more cable penetration holes or oil production channels to adapt to the application scheme of multiple electric submersible pumps.

[0076] In summary, the tubing-connected downhole gas release tool of this application effectively separates the packer and the tubing-connected downhole gas release tool into two separate products, making the packer and the tubing-connected downhole gas release tool completely independent. This allows the packer to be freed from the restriction of the vent valve, enabling it to be placed in deeper formations downhole. It also solves other interlocking problems. Gas is transported from the packer, which is far from the wellhead, to the tubing-connected downhole gas release tool, which is closer to the wellhead, via a longer gas pipeline. The gas is then transported into the tubing through the tubing-connected downhole gas release tool, thereby releasing the gas accumulated below the packer.

[0077] The tubing-connected downhole gas release tool guides the gas accumulated below the packer into the main tubing. Since the oil and gas recovered from the main tubing undergoes oil and gas separation in specialized equipment on the surface, this product re-aggregates the accumulated gas with the oil and gas in the main tubing and then enters the specialized equipment for oil and gas separation. This not only ensures the venting needs without increasing additional costs, but also eliminates the need to treat the released gas through the wellhead, improving the safety of downhole operations.

[0078] The tubing-connected downhole gas release tool is located at the top of the packer. It utilizes the principle that gas is lighter to ensure that gas is released from bottom to top, and the channel connected to the main tubing is in a relatively closed environment. This completely solves the problem of the packer vent being blocked due to the deposition of impurities in the annular space above the packer.

[0079] The above description is merely an embodiment of this application and is not intended to limit the scope of this application. Various modifications and variations can be made to this application by those skilled in the art. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of this application should be included within the scope of the claims of this application.

Claims

1. A downhole gas release tool with tubing connection, characterized in that, include: The oil pipe body (1) and the exhaust control mechanism (2) are provided. The oil pipe body (1) has an oil and gas main transport channel (11), a hydraulic control chamber (12) and an exhaust port (13). The hydraulic control chamber (12) is connected to the oil and gas main transport channel (11) and the exhaust port (13) respectively. The exhaust control mechanism (2) is located in the hydraulic control chamber (12). In the initial state, the exhaust port (13) is not connected to the oil and gas main transport channel (11). In the working state, the exhaust port (13) is connected to the oil and gas main transport channel (11). The oil pipe body (1) is provided with a first connecting hole (14) and a second connecting hole (15). The hydraulic control chamber (12) has an upper end (121) and a lower end (122). The upper end (121) is located above the gravity direction of the hydraulic control chamber (12), and the lower end (122) is located below the gravity direction of the hydraulic control chamber (12). The second connecting hole (15) is provided relative to the lower end (122). The first connecting hole (14) is provided between the upper end (121) and the lower end (122). The first connecting hole (14) connects the exhaust hole (13) and the hydraulic control chamber (12). The second connecting hole (15) connects the main oil and gas transport channel (11) and the hydraulic control chamber (12). The exhaust control mechanism (2) includes a sleeve (21), a spindle assembly (22), a sealing assembly (23), and a reset assembly (24). The sleeve (21) is fixedly disposed in the hydraulic control chamber (12), and the sleeve (21) has a first through hole (211) on its peripheral wall. The spindle assembly (22) includes an exhaust spindle (221) and a sealing piston (222). The exhaust spindle (221) is disposed in the sleeve (21), and the sealing piston (222) is sleeved on the exhaust spindle (221) and slidably connected to the sleeve (21). The sealing assembly (23) includes a first spacer (231), a second spacer (232), and a third spacer (233). The first spacer (231) is located at the end of the sealing piston (222) facing away from the second connecting hole (15), and it is sleeved on the exhaust spindle (221) and fixedly connected to the inner wall of the sleeve (21). The second spacer (231) is located at the end of the sealing piston (222) facing away from the second connecting hole (15). The first spacer (231) is sleeved on the exhaust spindle (221) and fixedly connected to the inner wall of the sleeve (21). The ring (232) is located at one end of the first connecting hole (14), and is sealed to the sleeve (21) and the cavity wall of the hydraulic control chamber (12) respectively. The third spacer ring (233) is located at the other end of the first connecting hole (14), and is sealed to the sleeve (21) and the cavity wall of the hydraulic control chamber (12) respectively. The second spacer ring (232) and the third spacer ring (233) are located at opposite ends of the first through hole (211) respectively. The reset assembly (24) is located inside the sleeve (21) and is connected to the exhaust mandrel (221). In the initial state, the sealing piston (222) blocks the first through hole (211), and the exhaust hole (13) is not connected to the main oil and gas transport channel (11). In the working state, the sealing piston (222) leaves the first through hole (211), and the exhaust hole (13) is connected to the main oil and gas transport channel (11). The vent (13) is connected to the packer via a hard pipe with a 3 / 8" NPT thread.

2. The tubing-connected downhole gas release tool according to claim 1, characterized in that, The exhaust mandrel (221) has a second through hole (2211) on its peripheral wall, and the second through hole (2211) is located between the first spacer ring (231) and the sealing piston (222).

3. The tubing-connected downhole gas release tool according to claim 1, characterized in that, The reset assembly (24) includes a limiting seat (241), a limiting block (242), and an elastic element (243). The limiting seat (241) is located on the side of the first spacer ring (231) facing away from the sealing piston (222) and is fixedly connected to the exhaust spindle (221). The limiting block (242) is located between the limiting seat (241) and the first spacer ring (231) and is engaged with the limiting seat (241). The elastic element (243) is located between the limiting block (242) and the first spacer ring (231), with one end abutting against the limiting block (242) and the other end abutting against the first spacer ring (231).

4. The tubing-connected downhole gas release tool according to claim 3, characterized in that, The outer wall of the exhaust mandrel (221) is provided with a groove (2212), the limiting seat (241) is provided in the groove (2212), the limiting block (242) has an abutting part (2421) and a locking part (2422), the abutting part (2421) abuts against the elastic member (243), and the locking part (2422) is located between the limiting seat (241) and the first spacer ring (231) and is locked with the limiting seat (241).

5. The tubing-connected downhole gas release tool according to claim 4, characterized in that, The reset assembly (24) also includes a top nut (244), which is located inside the sleeve (21) and at one end of the limiting seat (241) facing away from the first spacer (231), and its inner wall diameter is smaller than the outer diameter of the limiting block (242).

6. The tubing-connected downhole gas release tool according to claim 3, characterized in that, The reset assembly (24) further includes a lower plug (245), which is located inside the sleeve (21) and at one end of the sealing piston (222) facing away from the first spacer (231). The diameter of its inner wall surface is smaller than the outer diameter of the sealing piston (222).

7. The tubing-connected downhole gas release tool according to claim 3, characterized in that, The reset assembly (24) further includes a base (246), which is disposed on the first spacer (231) and located between the first spacer (231) and the elastic member (243). One end of the elastic member (243) abuts against the base (246) and the other end abuts against the limiting block (242).

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