Angle-adjustable directional drilling tools and ultra-short radius wave-type horizontal drilling method

Abstract

This application provides an angle-adjustable directional drilling tool and an ultra-short radius wave-type horizontal drilling method, relating to the field of oil and gas well drilling technology. An angle-adjustable directional drilling tool includes a partial drilling component, which comprises a rotating inner shaft, a non-rotating outer sleeve, and a drill bit connection. Three mounting windows are evenly arranged circumferentially on the sidewall of the non-rotating outer sleeve. A main directional drilling component is disposed within each mounting window, and an auxiliary directional drilling component is also disposed at each mounting window. The auxiliary directional drilling component increases the contact area between the main directional drilling component and the wellbore, thereby enhancing the stability of the reverse force exerted by the wellbore on the partial drilling component. By utilizing the radial expansion and contraction of the main directional drilling component to change the advance angle of the partial drilling component, and in conjunction with the auxiliary directional drilling component to increase the contact area with the wellbore, it can effectively prevent the force feedback from the wellbore to the guide block from dissipating or becoming insufficient, thus improving the accuracy of the drilling angle.

Description

Technical Field

[0001] This application relates to the field of oil and gas well drilling technology, and more specifically, to an angle-adjustable directional drilling tool and an ultra-short radius wave-type horizontal drilling method. Background Technology

[0002] Most oilfields in my country are characterized by thin, interbedded reservoirs consisting of alternating sandstone and mudstone layers. These reservoirs are characterized by thin individual layers (usually less than 3 meters), numerous layers, dispersed vertical distribution, and frequent sandstone-mudstone interleaving, resembling a "thousand-layer cake." Traditional development methods primarily rely on vertical wells or conventional horizontal wells. Vertical wells are limited by wellbore trajectory, resulting in limited oil layer thickness encountered per well and low vertical utilization. Conventional horizontal wells often employ linear trajectories, extending only along a single thin oil layer and making it difficult to cross interlayers to utilize adjacent oil layers, leading to low controlled reserves per well and poor development efficiency.

[0003] Therefore, there is an urgent need to propose an angle-adjustable directional drilling tool and an ultra-short radius wave-type horizontal drilling method. Through the wave-like undulation design of the trajectory, it is possible to "completely capture" the vertically dispersed thin oil layers. By repeatedly traversing multiple thin oil layers and interlayers, it is possible to achieve efficient utilization of multi-layered oil reservoirs.

[0004] In existing technologies, during the directional drilling process, the drill string needs to rely on the well wall to feed radial force back to the drill string in order to adjust the drilling direction of the drill bit. However, if the force fed back from the well wall to the drill string dissipates or becomes insufficient, it will cause the drilling path to be inconsistent with the expected one, which will seriously affect the actual use effect. Summary of the Invention

[0005] This application aims to at least solve one of the technical problems existing in the prior art. To this end, this application proposes an angle-adjustable directional drilling tool, including a partial drilling component. The partial drilling component includes a rotating inner shaft, a non-rotating outer sleeve, and a drill bit connection portion. The rotating inner shaft and the drill bit connection portion rotate coaxially and synchronously. The non-rotating outer sleeve is rotatably fitted onto both the rotating inner shaft and the drill bit connection portion. A positioning sleeve is coaxially fixedly disposed inside the non-rotating outer sleeve, and the positioning sleeve is rotatably fitted onto the rotating inner shaft. Three mounting windows are evenly arranged circumferentially on the side wall of the non-rotating outer sleeve, and the three mounting windows radially correspond to the positioning sleeve. A main directional drilling component is disposed within the mounting windows, and the main directional drilling component is coaxially fixedly fitted onto the positioning sleeve. The main directional drilling component extends radially within the mounting windows. The shrinkage change forms contact with the wellbore, thereby stopping the non-rotating outer sleeve from rotating and subjecting it to a reverse radial force from the wellbore, changing the advance angle of the local drill string component. The three main directional drilling components are evenly distributed axially on the non-rotating outer sleeve, which can improve the accuracy of the angle change of the local drill string component. An auxiliary directional drilling component is also provided at the mounting window. The auxiliary directional drilling component is elastically connected to the main directional drilling component, and the outward side of the auxiliary directional drilling component is sleeved on the main directional drilling component. The auxiliary directional drilling component and the main directional drilling component extend radially synchronously. The auxiliary directional drilling component is used to increase the contact area between the main directional drilling component and the wellbore, thereby enhancing the stability of the reverse force applied by the wellbore to the local drill string component.

[0006] Preferably, the main inclined component includes a fixed seat, a guide block, two hydraulic cylinders, and an arc-shaped connecting block. The fixed seat is sleeved around the periphery of the positioning sleeve. The guide block slides radially and sealingly on the fixed seat. One end of each of the two hydraulic cylinders is fixed to the positioning sleeve, and the other end of each of the two hydraulic cylinders is fixed to the inner side of the guide block. The arc-shaped connecting block is symmetrically fixed to the front and rear ends and the left and right sides of the fixed seat, and the arc-shaped connecting block and the positioning sleeve are fixedly connected.

[0007] Preferably, the same end of two adjacent fixing seats is fixed to both sides of the same arc-shaped connecting block.

[0008] Preferably, at least two first guide rods are symmetrically fixed inside the fixed base, and the guide block is slidably sleeved on the two first guide rods. The guide block is radially and slidably disposed at the center of the fixed base. Two guide strips are symmetrically arranged on the inner wall of the fixed base, and the two sides of the guide block and the two guide strips are in a sealing sliding fit.

[0009] Preferably, the guide block is arranged in a Z-shape, a reinforcing block is fixedly connected to the center of the inner side of the guide block, a plurality of protrusions are evenly arranged on the arc-shaped outer wall of the guide block, and a guide groove adapted to the guide strip is provided on the side wall of the guide block.

[0010] Preferably, the auxiliary tilting component includes an anti-collapse plate and four elastic members. The anti-collapse plate is embedded in the mounting window and slidably inserted into the arc-shaped connecting block. The four elastic members are symmetrically arranged between the anti-collapse plate and the guide block. The two ends of the elastic members are respectively fixed to the inner side of the anti-collapse plate and the guide block. The elastic members slide through the fixed base in a sealed manner.

[0011] Preferably, a plurality of protrusions are evenly arranged on the arc-shaped outer wall of the anti-collapse plate along the axial direction of the non-rotating outer sleeve, and four second guide rods are symmetrically fixed to the inner side of the anti-collapse plate, the second guide rods being sealed and slidably inserted into the arc-shaped connecting block.

[0012] Preferably, the elastic element includes a movable cylinder, a first sliding rod, a first spring, and a fixed cylinder. The movable cylinder is fixedly connected to the guide block. The first sliding rod is axially slidably inserted into the movable cylinder. The first spring is coaxially disposed inside the movable cylinder and abuts against the first sliding rod. The fixed cylinder is fixed to the anti-collapse plate and coaxially fixedly connected to the end of the first sliding rod away from the first spring.

[0013] Preferably, the fixed cylinder is slidably sleeved on the movable cylinder, and the fixed cylinder slidably passes through the fixed seat.

[0014] The adjustable-angle tilting tool of this application has the following advantages:

[0015] By utilizing the radial expansion and contraction of the main directional drilling component to change the forward angle of local drill string components, and in conjunction with the auxiliary directional drilling component to increase the contact area between the component and the wellbore, it can effectively prevent the force fed back from the wellbore to the guide block from dissipating or becoming insufficient, thereby improving the accuracy of the drilling angle.

[0016] By utilizing the elastic relationship between the auxiliary and main directional drilling components, the accuracy of the force feedback from the wellbore to the guide block can be further improved, and the large additional reverse force generated by the auxiliary directional drilling components due to expansion and contraction can be reduced.

[0017] The MWD system is used to achieve real-time monitoring and transmission of trajectory parameters, ensuring the timeliness and accuracy of trajectory adjustments;

[0018] Drill string and drilling fluid optimization involves optimizing drill collar stiffness distribution based on the curvature variations of different well sections along the wave trajectory, reducing stress concentration caused by abrupt stiffness changes, selecting high-strength alloy drill collars and flexible drill pipes to improve the overall bending and torsional resistance of the drill string, and applying surface nano-reinforcement technology to treat key parts of the drill string to further improve surface hardness and wear resistance, reducing fatigue damage. By selecting high-efficiency inhibitors and plugging agents, the drilling fluid's ability to suppress mudstone is enhanced, controlling the mudstone hydration and expansion rate. Optimizing drilling fluid rheological parameters improves the drilling fluid's sand-carrying capacity and lubrication performance, reducing friction between the drill string and the wellbore, preventing stuck pipe due to excessive friction during trajectory adjustment, and adding anti-fouling agents enhances the drilling fluid's adaptability to formation contaminants, ensuring wellbore stability.

[0019] On the other hand, this application also provides an ultra-short radius wave-type horizontal drilling method, including the following steps:

[0020] S1: Establish a dynamic optimization model for wave trajectory: Based on the three-dimensional geological model of the reservoir, establish a dynamic optimization model for wave trajectory, considering the mechanical characteristics of the drill string and the interaction between the wellbore and the formation, calculate the trajectory adjustment angle and orientation in real time, realize the dynamic correction and optimization of the trajectory, and ensure that the wellbore accurately crosses the target oil layer.

[0021] S2: Integrating the Measurement While Drilling (MWD) system, forming an integrated toolchain of "high-adjustability motor + MWD". The high-adjustability motor can provide a larger build-up rate, and the MWD system realizes real-time monitoring and transmission of trajectory parameters, ensuring the timeliness and accuracy of trajectory adjustment. Through tool integration and algorithm optimization, the horizontal section trajectory adjustment capability reaches more than 40° / 30m, providing core support for the realization of wave trajectory.

[0022] S3: Drill string optimization and drilling fluid optimization. Based on the curvature changes of different well sections of the wave trajectory, the stiffness distribution of the drill collar is optimized to reduce stress concentration caused by abrupt stiffness changes. High-strength alloy drill collars and flexible drill pipes are selected to improve the overall bending and torsional resistance of the drill string. Surface nano-reinforcement technology is applied to treat key parts of the drill string to further improve the surface hardness and wear resistance of the drill string and reduce fatigue damage. By selecting high-efficiency inhibitors and plugging agents, the drilling fluid's ability to inhibit mudstone is enhanced, the mudstone hydration expansion rate is controlled, the rheological parameters of the drilling fluid are optimized, the sand-carrying capacity and lubrication performance of the drilling fluid are improved, the friction between the drill string and the wellbore is reduced, and the sticking of the drill string due to excessive friction during trajectory adjustment is avoided. Anti-contamination agents are added to improve the drilling fluid's adaptability to formation contaminants and ensure wellbore stability.

[0023] S4: Coiled tubing directional guide: The coiled tubing directional guide string is used. The bottom of the coiled tubing is equipped with the directional guide. The directional guide is lowered into the designed window position inside the casing. After adjusting the orientation of the directional guide through drilling measurement and directional control, it is mounted on the inner wall of the casing.

[0024] S5: Continuous tubing casing window opening, milling the inner wall of the casing along the inclined surface of the directional tool to complete the casing window opening and window trimming operation, forming a window for side drilling;

[0025] S6: Coiled tubing directional drilling and horizontal section drilling: Through the formed window, the coiled tubing directional drilling string enters the formation, and the wellbore trajectory is monitored and controlled in real time by the measurement while drilling instrument to carry out ultra-short radius directional drilling and horizontal section drilling to form a horizontal side-drilled wellbore;

[0026] S7: Horizontal section directional drilling. Through the expansion and contraction of three main directional drilling components and corresponding auxiliary directional drilling components set in the circumferential direction within the installation window, the well wall transmits a reverse radial force to the local drilling tool components, thereby changing the advance angle of the local drilling tool components. According to the MWD system, the trajectory parameters are monitored and transmitted in real time, ensuring the timeliness and accuracy of trajectory adjustment. Ultimately, a wave-like drilling trajectory is achieved, with vertical adjustment of 2m for every 40m well section and 2-4 passes through layers in a 150m horizontal section.

[0027] Additional aspects and advantages of this application will be set forth in part in the description which follows, and in part will be obvious from the description, or may be learned by practice of this application. Attached Figure Description

[0028] To more clearly illustrate the technical solutions of the embodiments of this application, the drawings used in the embodiments will be briefly introduced below. It should be understood that the following drawings only show some embodiments of this application and should not be regarded as a limitation of the scope. For those skilled in the art, other related drawings can be obtained from these drawings without creative effort.

[0029] Figure 1 This is a schematic diagram of the overall structure of an angle-adjustable tilting tool according to an embodiment of this application;

[0030] Figure 2 This is a cross-sectional view of an angle-adjustable tilting tool according to an embodiment of this application;

[0031] Figure 3 This is a schematic diagram of the structure of a partial drilling tool component according to an embodiment of this application;

[0032] Figure 4 This is a schematic diagram of the main tilting component and the auxiliary tilting component according to an embodiment of this application;

[0033] Figure 5 This is an exploded view of the main tilting component and the auxiliary tilting component according to an embodiment of this application;

[0034] Figure 6This is a partial structural cross-sectional view of the main tilting component and the auxiliary tilting component according to an embodiment of this application;

[0035] Figure 7 This is a partial exploded view of the main inclined component according to an embodiment of this application;

[0036] Figure 8 This is a partial structural cross-sectional view of the auxiliary tilting component according to an embodiment of this application;

[0037] Figure 9 This is a cross-sectional view of the elastic element according to an embodiment of this application;

[0038] Figure 10 This is a schematic diagram showing the position of the reinforced tilting component according to an embodiment of this application;

[0039] Figure 11 This is a partial exploded view of the reinforced tilting component according to an embodiment of this application;

[0040] Figure 12 This is a partial structural cross-sectional view of the non-rotating jacket according to an embodiment of this application;

[0041] Figure 13 According to the embodiments of this application Figure 11 Enlarged view of A in the middle;

[0042] Figure 14 This is a partial structural schematic diagram of a drilling tool component according to an embodiment of this application;

[0043] Figure 15 This is a partial structural schematic diagram of the auxiliary component according to an embodiment of this application;

[0044] Figure 16 According to the embodiments of this application Figure 14 A magnified view of B in the middle.

[0045] Icons: 1. Partial drill string component; 11. Rotating inner shaft; 12. Non-rotating outer sleeve; 121. Positioning sleeve; 122. Mounting window; 123. Annular chamber; 124. Radial sliding chamber; 125. Reinforcing chamber; 126. Axial sliding chamber; 13. Drill bit connection; 2. Main directional drilling component; 21. Fixed seat; 211. First guide rod; 212. Guide strip; 22. Guide block; 221. Reinforcing block; 222. Protrusion; 223. Guide groove; 23. Hydraulic cylinder; 24. Arc 3. Auxiliary inclined plate component; 31. Anti-collapse plate; 311. Protruding strip; 312. Second guide rod; 32. Elastic component; 321. Movable cylinder; 322. First sliding rod; 323. First spring; 324. Fixed cylinder; 4. Reinforced inclined plate component; 41. Inclined panel; 42. Abutment plate; 421. Second sliding rod; 422. Second spring; 5. Auxiliary component; 51. Fixed plate; 52. Reinforcing plate; 53. Reset component; 531. Fixed rod; 532. Third spring. Detailed Implementation

[0046] To make the objectives, technical solutions, and advantages of the embodiments of this application clearer, the technical solutions of the embodiments of this application will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only a part of the embodiments of this application, not all of them. Based on the embodiments of this application, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of this application. Example 1

[0047] like Figures 1-9 As shown, an angle-adjustable directional drilling tool according to an embodiment of this application includes a partial drilling component 1. The partial drilling component 1 includes a rotating inner shaft 11, a non-rotating outer sleeve 12, and a drill bit connection part 13. The rotating inner shaft 11 and the drill bit connection part 13 rotate coaxially and synchronously. The non-rotating outer sleeve 12 is rotatably sleeved on the rotating inner shaft 11 and the drill bit connection part 13 respectively. It should be noted that this application adopts rotary steering technology. In the field of petroleum exploration and mining technology, rotary steering technology is common knowledge to those skilled in the art. Therefore, the specific power system, power transmission, etc. will not be described in detail here.

[0048] In a specific embodiment of this application, a positioning sleeve 121 is coaxially fixed inside the non-rotating outer sleeve 12. The positioning sleeve 121 is rotatably sleeved on the rotating inner shaft 11. Three mounting windows 122 are evenly arranged circumferentially on the side wall of the non-rotating outer sleeve 12, and the three mounting windows 122 are radially corresponding to the positioning sleeve 121.

[0049] Therefore, it can be seen that the positioning sleeve 121 and the rotating inner shaft 11 are rotatably connected, and the non-rotating outer sleeve 12 and the rotating inner shaft 11 are also rotatably connected. Thus, the positioning sleeve 121 and the non-rotating outer sleeve 12 can maintain a relatively stationary state.

[0050] Furthermore, a main directional drilling component 2 is provided inside the mounting window 122. The main directional drilling component 2 is coaxially fixedly sleeved on the positioning sleeve 121. The main directional drilling component 2 undergoes radial expansion and contraction within the mounting window 122, forming contact with the well wall, thereby stopping the rotation of the non-rotating outer sleeve 12 and receiving a reverse radial force from the well wall, thus changing the advance angle of the local drilling component 1. The three main directional drilling components 2 are evenly distributed axially in the non-rotating outer sleeve 12, which can improve the accuracy of the angle change of the local drilling component 1.

[0051] Specifically, such as Figures 4-6 As shown, the main inclined component 2 includes a fixed base 21, a guide block 22, two hydraulic cylinders 23 and an arc-shaped connecting block 24. The fixed base 21 is sleeved around the positioning sleeve 121. The guide block 22 is radially sealed and slides on the fixed base 21. One end of the two hydraulic cylinders 23 is fixed to the positioning sleeve 121, and the other end of the two hydraulic cylinders 23 is fixed to the inner side of the guide block 22. The arc-shaped connecting block 24 is symmetrically fixed to the front and rear ends and the left and right sides of the fixed base 21, and the arc-shaped connecting block 24 and the positioning sleeve 121 are fixedly connected.

[0052] It should be noted that the two hydraulic cylinders 23 located in the same guide block 22 keep synchronously extending and retracting to ensure that the guide block 22 forms a radial displacement parallel to the axis of the non-rotating outer sleeve 12 at the corresponding mounting window 122, so as to avoid the guide block 22 tilting during the radial displacement process.

[0053] In this case, the same end of two adjacent fixed seats 21 are respectively fixed to both sides of the same arc-shaped connecting block 24.

[0054] It is understandable that the three fixed seats 21 are fixedly connected to the three arc-shaped connecting blocks 24 at both ends, and are fixedly fitted on the positioning sleeve 121, thus ensuring a stable connection between the positioning sleeve 121 and the main inclined component 2 on it.

[0055] like Figure 7 As shown, it should be noted that at least two first guide rods 211 are symmetrically fixed inside the fixed seat 21, and the guide block 22 is slidably sleeved on the two first guide rods 211. The guide block 22 is radially sealed and slidably disposed at the center of the fixed seat 21. Two guide strips 212 are symmetrically disposed on the inner wall of the fixed seat 21, and the two sides of the guide block 22 and the two guide strips 212 are sealed and slidably engaged.

[0056] Therefore, when the guide block 22 generates radial displacement within the fixed seat 21, under the multi-directional guiding action, it further ensures the stability of the displacement and avoids tilting, which in turn affects the thrust it generates on the well wall and the guiding effect on the local drilling tool component 1.

[0057] The guide block 22 is arranged in a Z-shape. A reinforcing block 221 is fixedly connected to the center of the inner side of the guide block 22. Multiple protrusions 222 are evenly arranged on the arc-shaped outer wall of the guide block 22. A guide groove 223 that matches the guide strip 212 is provided on the side wall of the guide block 22.

[0058] Understandably, the reinforcing block 221 can ensure the rigidity of the guide block 22 and enhance its performance. The multiple protrusions 222 can enhance the friction between the guide block 22 and the well wall. After the guide block 22 extends and abuts against the well wall, it can ensure that the non-rotating outer sleeve 12 does not rotate with the rotating inner shaft 11 and that the guide block 22 only follows the entire local drill string component 1 forward. In this way, the guiding effect can be enhanced.

[0059] Further, such as Figure 2 , Figures 3-6 as well as Figure 8 and Figure 9 As shown, an auxiliary directional drilling component 3 is also provided at the installation window 122. The auxiliary directional drilling component 3 is elastically connected to the main directional drilling component 2, and the outward side of the auxiliary directional drilling component 3 is sleeved on the main directional drilling component 2. The auxiliary directional drilling component 3 and the main directional drilling component 2 extend radially synchronously. The auxiliary directional drilling component 3 is used to increase the contact area between the main directional drilling component 2 and the well wall, thereby enhancing the stability of the reverse force applied by the well wall to the local drilling tool component 1.

[0060] The auxiliary inclined component 3 includes an anti-collapse plate 31 and four elastic members 32. The anti-collapse plate 31 is embedded in the installation window 122 and slidably inserted into the arc-shaped connecting block 24. The four elastic members 32 are symmetrically arranged between the anti-collapse plate 31 and the guide block 22. The two ends of the elastic members 32 are respectively fixed to the inner side of the anti-collapse plate 31 and the guide block 22. The elastic members 32 are sealed and slidably penetrate the fixed seat 21.

[0061] It should be noted that multiple protrusions 311 are evenly arranged on the arc-shaped outer wall of the anti-collapse plate 31 along the axial direction of the non-rotating outer sleeve 12, and four second guide rods 312 are symmetrically fixed to the inner side of the anti-collapse plate 31. The second guide rods 312 are sealed and slidably inserted into the arc-shaped connecting block 24.

[0062] It is understandable that the multiple convex strips 311 arranged along the axial direction serve two purposes: firstly, to ensure the friction between the arc-shaped outer wall of the anti-collapse plate 31 and the well wall in the direction of rotation, effectively limiting rotation; secondly, the spacing between the multiple convex strips 311 during the entire advance of the local drilling tool component 1 can effectively reduce the forward resistance. Furthermore, it is understandable that the four second guide rods 312 are respectively sealed and slidably inserted into the arc-shaped connecting block 24, which can further ensure the stability between the anti-collapse plate 31 itself and the main skewing component 2 after radial extension, avoiding the occurrence of displacement.

[0063] Furthermore, the elastic element 32 includes a movable cylinder 321, a first sliding rod 322, a first spring 323, and a fixed cylinder 324. The movable cylinder 321 is fixedly connected to the guide block 22. The first sliding rod 322 is axially slidably inserted into the movable cylinder 321. The first spring 323 is coaxially disposed inside the movable cylinder 321 and abuts against the first sliding rod 322. The fixed cylinder 324 is fixed to the anti-collapse plate 31 and is coaxially fixedly connected to the end of the first sliding rod 322 away from the first spring 323.

[0064] The fixed cylinder 324 is slidably sleeved on the movable cylinder 321, and the fixed cylinder 324 is sealed and slidably penetrates the fixed seat 21.

[0065] In a specific embodiment of this application, it should be noted that the thickness of the anti-collapse plate 31 is less than the thickness of the guide block 22, and in the initial state (i.e., when both are contracted and do not extend beyond the outer wall of the non-rotating outer sleeve 12), the anti-collapse plate 31 covers the fixed seat 21, and the outer wall of the anti-collapse plate 31 and the outer wall of the guide block 22 are located in the same curved surface.

[0066] Therefore, it can be understood that when the guide block 22 extends radially outward under the action of the hydraulic cylinder 23, the guide block 22 will drive the movable cylinder 321 to move synchronously and in the same direction. At this time, the outward radial force will be transmitted to the first slide rod 322 through the first spring 323, and will also transmit a flexible outward radial force to the anti-collapse plate 31, causing the anti-collapse plate 31 to also move radially outward. When the well wall is relatively solid and there is no collapse or instability, after the guide block 22 abuts against the well wall, the well wall will feed back a precise reverse force to the corresponding guide block 22, and cause the local drilling tool component 1 to change its angle. If the well wall collapses or becomes unstable, the guide block 22 will continue to extend after abutting against the well wall. At this time, the anti-collapse plate 31 will also move radially outward. During the displacement process, the collapse plate 31 will abut against the well wall. Because its own force-bearing area is significantly larger than that of the guide block 22, it will be hindered in radial displacement and will transmit the force in the opposite direction to the guide block 22 through elastic change. As the first spring 323 is continuously compressed or even compressed to the extreme, the guide block 22 will receive a more precise reverse force and transmit it to the local drill tool component 1 to change its angle. Conversely, when the direction changes, the corresponding guide block 22 will reset. During the reset process, the anti-collapse plate 31 will be subjected to the tension applied to the first slide rod 322 by the movable cylinder 321, and finally the anti-collapse plate 31 will complete the reset (in this state, the first slide rod 322 is located at the radially outward end of the movable cylinder 321).

[0067] On the other hand, embodiments of this application also provide an ultra-short radius wave-type horizontal drilling method, including the following steps:

[0068] S1: Establish a dynamic optimization model for wave trajectory: Based on the three-dimensional geological model of the reservoir, establish a dynamic optimization model for wave trajectory, considering the mechanical characteristics of the drill string and the interaction between the wellbore and the formation, calculate the trajectory adjustment angle and orientation in real time, realize the dynamic correction and optimization of the trajectory, and ensure that the wellbore accurately crosses the target oil layer.

[0069] S2: Integrating the Measurement While Drilling (MWD) system, forming an integrated toolchain of "high-adjustability motor + MWD". The high-adjustability motor can provide a larger build-up rate, and the MWD system realizes real-time monitoring and transmission of trajectory parameters, ensuring the timeliness and accuracy of trajectory adjustment. Through tool integration and algorithm optimization, the horizontal section trajectory adjustment capability reaches more than 40° / 30m, providing core support for the realization of wave trajectory.

[0070] S3: Drill string optimization and drilling fluid optimization. Based on the curvature changes of different well sections of the wave trajectory, the stiffness distribution of the drill collar is optimized to reduce stress concentration caused by abrupt stiffness changes. High-strength alloy drill collars and flexible drill pipes are selected to improve the overall bending and torsional resistance of the drill string. Surface nano-reinforcement technology is applied to treat key parts of the drill string to further improve the surface hardness and wear resistance of the drill string and reduce fatigue damage. By selecting high-efficiency inhibitors and plugging agents, the drilling fluid's ability to inhibit mudstone is enhanced, the mudstone hydration expansion rate is controlled, the rheological parameters of the drilling fluid are optimized, the sand-carrying capacity and lubrication performance of the drilling fluid are improved, the friction between the drill string and the wellbore is reduced, and the sticking of the drill string due to excessive friction during trajectory adjustment is avoided. Anti-contamination agents are added to improve the drilling fluid's adaptability to formation contaminants and ensure wellbore stability.

[0071] S4: Coiled tubing directional guide: The coiled tubing directional guide string is used. The bottom of the coiled tubing is equipped with the directional guide. The directional guide is lowered into the designed window position inside the casing. After adjusting the orientation of the directional guide through drilling measurement and directional control, it is mounted on the inner wall of the casing.

[0072] S5: Continuous tubing casing window opening, milling the inner wall of the casing along the inclined surface of the directional drill to complete the casing window opening and window trimming operation, forming a window for side drilling;

[0073] S6: Coiled tubing directional drilling and horizontal section drilling. Through the formed window, the coiled tubing directional drilling string enters the formation. The wellbore trajectory is monitored and controlled in real time by the measurement while drilling instrument. Ultra-short radius directional drilling and horizontal section drilling are carried out to form a horizontal side-drilled wellbore.

[0074] S7: Horizontal section directional drilling. Through the expansion and contraction of three main directional drilling components 2 and corresponding auxiliary directional drilling components 3 set in the circumferential direction within the installation window 122, the well wall transmits a reverse radial force to the local drilling tool component 1, thereby changing the advance angle of the local drilling tool component 1. The trajectory parameters are monitored and transmitted in real time according to the MWD system, ensuring the timeliness and accuracy of trajectory adjustment. Ultimately, a wave-like drilling trajectory is achieved, with vertical adjustment of 2m for every 40m well section and 2-4 passes through layers in the 150m horizontal section. Example 2

[0075] In related technologies, when the guide block 22 contacts the well wall and forms a reverse force to change the forward angle of the local drilling tool component 1, the accuracy of the angle change is also affected by the forward speed of the local drilling tool component 1. Furthermore, when the auxiliary directional drilling component 3 is in contact with the guide block 22 and the well wall, due to its own thickness, it is more likely to be damaged than the guide block 22. Once damaged, it will reduce the accuracy of the change of the forward angle of the entire local drilling tool component 1.

[0076] According to some embodiments of this application, such as Figures 10-13As shown, a reinforced directional drilling component 4 is also provided inside the non-rotating outer sleeve 12. The reinforced directional drilling component 4 is located at one end of the auxiliary directional drilling component 3 facing the drill bit connection part 13. The reinforced directional drilling component 4 undergoes radial and axial changes as the auxiliary directional drilling component 3 expands and contracts radially, and makes the auxiliary directional drilling component 3 present an inclined surface in the direction of forward movement.

[0077] It should be noted that an annular chamber 123 is coaxially arranged inside the non-rotating outer sleeve 12. The annular chamber 123 is located at one end of the mounting window 122 facing the drill bit connection part 13. A radial sliding chamber 124 is also arranged inside the mounting window 122. A reinforcing chamber 125 is arranged inside the radial sliding chamber 124. An axial sliding chamber 126 is arranged along the axial direction on the side wall of the radial sliding chamber 124 facing the drill bit connection part 13.

[0078] The reinforced inclined component 4 includes an inclined panel 41 and an abutment plate 42. Both the inclined panel 41 and the abutment plate 42 are arc-shaped, and the two sides of the inclined panel 41 are parallel.

[0079] It should be noted that, as Figure 11 As shown, the inclined panel 41 is set at an angle, with its outward end facing the rear and its inward end facing the forward direction.

[0080] It is understandable that the parallel arrangement of the two sides of the inclined panel 41 can increase its axial cross-sectional area after radial extension, that is, increase its contact area with the outside world during the forward movement.

[0081] It should be noted that the inclined panel 41 is fixed to the end of the anti-collapse plate 31, and the inclined panel 41 slides in the radial sliding chamber 124. Therefore, the inclined panel 41 and the anti-collapse plate 31 move synchronously.

[0082] Furthermore, one end of the abutment plate 42 is elastically sealed and slides on the axial sliding chamber 126 and seals against the arc-shaped surface of the inclined panel 41.

[0083] It should be noted that a second slide rod 421 is fixedly connected axially inside the axial sliding chamber 126, and a second spring 422 is sleeved on the second slide rod 421. The abutment plate 42 is slidably sleeved on the second slide rod 421 and abuts against the second spring 422.

[0084] Therefore, it can be understood that when the inclined plate 41 moves radially outward following the anti-collapse plate 31, firstly, the inclined plate 41 will press the abutment plate 42 to move axially toward the interior of the axial sliding chamber 126, and compress the second spring 422. After the inclined plate 41 extends out of the non-rotating outer sleeve 12, it will come into contact with the outside and provide a reverse force toward the axis and a reverse force toward the rearward direction to the non-rotating outer sleeve 12 during the forward movement. Due to the forward movement, it can form a more effective reverse force with the collapsed well wall. The radial reverse force will be transmitted to the corresponding guide block 22 through the anti-collapse plate 31, further enhancing the accuracy of guidance. The reverse force opposite to the forward direction will exert pressure on local drilling tool components. 1. It generates a certain forward resistance, which reduces the forward speed to a certain extent. Combined with the radial counterforce, it can further improve the guiding accuracy. Furthermore, when the inclined panel 41 retracts along with the anti-collapse plate 31, under the elastic force of the second spring 422, the abutment plate 42 will gradually extend and ensure that it always abuts against the arc-shaped outer wall of the inclined panel 41, removing any dirt that may be attached to the arc-shaped outer wall of the inclined panel 41, ensuring the accuracy of the counterforce generated in the next use. In addition, it can be understood that due to the inclination of the inclined panel 41, it will ensure that the corresponding anti-collapse plate 31 is reduced from the forward direction during use, effectively improving the service life of the anti-collapse plate 31. Example 3

[0085] In related technologies, the inclined plate 41 is subject to impacts in the forward direction during use, and reduces the forward speed of the local drill tool component 1 through the force it receives. Therefore, its rigidity, or stability on the anti-collapse plate 31, is particularly important.

[0086] According to some embodiments of this application, such as Figures 14-16 As shown, an auxiliary component 5 is provided inside the reinforced chamber 125. The auxiliary component 5 includes a fixing plate 51, a reinforcing plate 52, and a resetting component 53. The fixing plate 51 is fixed to the outward end of the reinforced chamber 125. The reinforcing plate 52 is fixed to the bottom end of the inclined panel 41 and slides in the reinforced chamber 125. The end of the reinforcing plate 52 away from the inclined panel 41 abuts against the side wall of the reinforced chamber 125 facing the forward direction. One end of the resetting component 53 is fixed to the fixing plate 51 and the other end is fixed to the inward side of the reinforced chamber 125. The reinforcing plate 52 is slidably sleeved on the resetting component 53.

[0087] Furthermore, the reset member 53 includes a fixing rod 531 and a third spring 532. One end of the fixing rod 531 is fixed to the fixing plate 51 and the other end is fixed to the inward side of the reinforcing chamber 125. The reinforcing plate 52 is slidably sleeved on the fixing rod 531. The third spring 532 is sleeved on the fixing rod 531. One end of the third spring 532 abuts against the fixing plate 51 and the other end abuts against the reinforcing plate 52.

[0088] Therefore, it can be understood that when the inclined plate 41 extends radially, it will drive the inner fixing plate 51 to slide along the reinforcing chamber 125. Through the contact between the fixing plate 51 and the side wall of the reinforcing chamber 125 facing the forward direction, as well as the fixed connection between the inclined plate 41 itself and the anti-collapse plate 31, a stable structure is formed, which avoids deformation or changes in tilt angle under continuous impact. This can improve the accuracy of the inclined plate 41. Secondly, the third spring 532 will be squeezed by the fixing plate 51 during the extension of the inclined plate 41. Therefore, during the inward retraction of the inclined plate 41, the elastic force of the third spring 532 will improve the retraction efficiency. It can also effectively promote the active retraction of the inclined plate 41 and the anti-collapse plate 31 when there is no tension between the movable cylinder 321 and the first sliding rod 322, so as to avoid the impact of untimely retraction on the tilting accuracy.

[0089] It should be noted that the specific models and specifications of the rotating inner shaft 11, the non-rotating outer sleeve 12, the drill bit connection part 13, the hydraulic cylinder 23, the first spring 323, the second spring 422, and the third spring 532 need to be selected and determined according to the actual specifications of the device. The specific selection and calculation method adopts the existing technology in this field, so it will not be described in detail.

[0090] The above are merely preferred embodiments of this application and are not intended to limit 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 protection of this application.

Claims

1. An angle-adjustable directional drilling tool, comprising a partial drilling component (1), wherein the partial drilling component (1) includes a rotating inner shaft (11), a non-rotating outer sleeve (12), and a drill bit connection portion (13), wherein the rotating inner shaft (11) and the drill bit connection portion (13) rotate coaxially and synchronously, and the non-rotating outer sleeve (12) is rotatably sleeved on the rotating inner shaft (11) and the drill bit connection portion (13), characterized in that: The non-rotating outer sleeve (12) is coaxially fixedly provided with a positioning sleeve (121), which is rotatably sleeved on the rotating inner shaft (11). The non-rotating outer sleeve (12) has three mounting windows (122) evenly arranged circumferentially on its side wall, and the three mounting windows (122) are radially corresponding to the positioning sleeve (121). The installation window (122) is provided with a main directional drilling component (2). The main directional drilling component (2) is coaxially fixedly sleeved on the positioning sleeve (121). The main directional drilling component (2) undergoes radial expansion and contraction within the installation window (122) to form an abutment with the well wall, thereby stopping the rotation of the non-rotating outer sleeve (12) and receiving a reverse radial force from the well wall, which changes the forward angle of the local drilling component (1). The three main directional drilling components (2) are evenly distributed axially in the non-rotating outer sleeve (12), which can improve the accuracy of the angle change of the local drilling component (1). The main inclined component (2) includes a fixed seat (21), a guide block (22), two hydraulic cylinders (23) and an arc-shaped connecting block (24). The fixed seat (21) is sleeved around the positioning sleeve (121). The guide block (22) is radially sealed and slides on the fixed seat (21). One end of the two hydraulic cylinders (23) is fixed to the positioning sleeve (121), and the other end of the two hydraulic cylinders (23) is fixed to the inner side of the guide block (22). The arc-shaped connecting block (24) is symmetrically fixed to the front and rear ends and the left and right sides of the fixed seat (21), and the arc-shaped connecting block (24) and the positioning sleeve (121) are fixedly connected. An auxiliary directional drilling component (3) is also provided at the installation window (122). The auxiliary directional drilling component (3) is elastically connected to the main directional drilling component (2), and the outward side of the auxiliary directional drilling component (3) is sleeved on the main directional drilling component (2). The auxiliary directional drilling component (3) and the main directional drilling component (2) extend radially synchronously. The auxiliary directional drilling component (3) is used to increase the contact area between the main directional drilling component (2) and the well wall, thereby enhancing the stability of the reverse force exerted by the well wall on the local drilling component (1). The auxiliary tilting component (3) includes an anti-collapse plate (31) and four elastic elements (32). The anti-collapse plate (31) is embedded in the mounting window (122) and slidably inserted into the arc-shaped connecting block (24). The four elastic elements (32) are symmetrically arranged between the anti-collapse plate (31) and the guide block (22). The two ends of the elastic elements (32) are fixed to the inner side of the anti-collapse plate (31) and the guide block (22) respectively. The elastic elements (32) are sealed and slidably penetrate the fixed seat (21).

2. The angle-adjustable skewer as described in claim 1, characterized in that: The same end of two adjacent fixing seats (21) is respectively fixed to both sides of the same arc-shaped connecting block (24).

3. The angle-adjustable tilting tool as described in claim 1, characterized in that: At least two first guide rods (211) are symmetrically fixed inside the fixed seat (21), and the guide block (22) is slidably sleeved on the two first guide rods (211). The guide block (22) is radially sealed and slidably disposed at the center of the fixed seat (21). The inner wall of the fixed base (21) is symmetrically provided with two guide strips (212), and the two sides of the guide block (22) and the two guide strips (212) are sealed and slidingly engaged.

4. The angle-adjustable skewer as described in claim 3, characterized in that: The guide block (22) is arranged in a Z-shape. A reinforcing block (221) is fixedly connected to the center of the inner side of the guide block (22). Multiple protrusions (222) are evenly arranged on the arc-shaped outer wall of the guide block (22). A guide groove (223) that matches the guide strip (212) is provided on the side wall of the guide block (22).

5. The angle-adjustable skewer as described in claim 1, characterized in that: Multiple protrusions (311) are uniformly arranged on the arc-shaped outer wall of the anti-collapse plate (31) along the axial direction of the non-rotating outer sleeve (12). Four second guide rods (312) are symmetrically fixed to the inner side of the anti-collapse plate (31). The second guide rods (312) are sealed and slidably inserted into the arc-shaped connecting block (24).

6. The angle-adjustable skewer as described in claim 1, characterized in that: The elastic element (32) includes a movable cylinder (321), a first slide rod (322), a first spring (323), and a fixed cylinder (324). The movable cylinder (321) is fixed to the guide block (22). The first slide rod (322) is axially slidably inserted into the movable cylinder (321). The first spring (323) is coaxially disposed inside the movable cylinder (321) and abuts against the first slide rod (322). The fixed cylinder (324) is fixed to the anti-collapse plate (31). The fixed cylinder (324) is coaxially fixed to the end of the first slide rod (322) away from the first spring (323).

7. The angle-adjustable skewer as described in claim 6, characterized in that: The fixed cylinder (324) is slidably sleeved on the movable cylinder (321), and the fixed cylinder (324) slides through the fixed seat (21) in a sealed manner.

8. A method for ultra-short radius wave-type horizontal drilling, characterized in that, Using an angle-adjustable tilting tool as described in any one of claims 1-7, the method includes the following steps: S1: Establish a dynamic optimization model for wave trajectory: Based on the three-dimensional geological model of the reservoir, establish a dynamic optimization model for wave trajectory, considering the mechanical characteristics of the drill string and the interaction between the wellbore and the formation, calculate the trajectory adjustment angle and orientation in real time, realize the dynamic correction and optimization of the trajectory, and ensure that the wellbore accurately crosses the target oil layer. S2: Integrating the Measurement While Drilling (MWD) system, forming an integrated toolchain of "high-adjustability motor + MWD". The high-adjustability motor can provide a larger build-up rate, and the MWD system realizes real-time monitoring and transmission of trajectory parameters, ensuring the timeliness and accuracy of trajectory adjustment. Through tool integration and algorithm optimization, the horizontal trajectory adjustment capability reaches more than 40° / 30m, providing core support for the realization of wave trajectory. S3: Drill string optimization and drilling fluid optimization. Based on the curvature changes of different well sections of the wave trajectory, the stiffness distribution of the drill collar is optimized to reduce stress concentration caused by abrupt stiffness changes. High-strength alloy drill collars and flexible drill pipes are selected to improve the overall bending and torsional resistance of the drill string. Surface nano-strengthening technology is applied to treat key parts of the drill string to further improve the surface hardness and wear resistance of the drill string and reduce fatigue damage. Through efficient inhibitors and plugging agents, the drilling fluid's ability to inhibit mudstone is enhanced, the mudstone hydration expansion rate is controlled, the rheological parameters of the drilling fluid are optimized, the sand-carrying capacity and lubrication performance of the drilling fluid are improved, the friction between the drill string and the wellbore is reduced, and the sticking of the drill string due to excessive friction during trajectory adjustment is avoided. Anti-contamination agents are added to improve the drilling fluid's adaptability to formation contaminants and ensure wellbore stability. S4: Coiled tubing directional guide: The coiled tubing directional guide string is used. The bottom of the coiled tubing is equipped with the directional guide. The directional guide is lowered into the designed window position inside the casing. After adjusting the orientation of the directional guide through drilling measurement and directional control, it is mounted on the inner wall of the casing. S5: Continuous tubing casing window opening, milling the inner wall of the casing along the inclined surface of the directional tool to complete the casing window opening and window trimming operation, forming a window for side drilling; S6: Coiled tubing directional drilling and horizontal section drilling: Through the formed window, the coiled tubing directional drilling string enters the formation, and the wellbore trajectory is monitored and controlled in real time by the measurement while drilling instrument to carry out ultra-short radius directional drilling and horizontal section drilling to form a horizontal side-drilled wellbore; S7: Horizontal section directional drilling, through the expansion and contraction of three main directional drilling components (2) and corresponding auxiliary directional drilling components (3) set in the circumferential direction within the installation window (122), the well wall transmits the reverse radial force to the local drilling component (1), thereby changing the forward angle of the local drilling component (1), and realizing the real-time monitoring and transmission of trajectory parameters according to the MWD system, ensuring the timeliness and accuracy of trajectory adjustment, and finally realizing a wave-like drilling trajectory that is vertically adjustable by 2m for every 40m well section and crosses layers 2-4 times in the 150m horizontal section.

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