While-drilling sound wave automatic shaft tracking tool and using method thereof

Abstract

The invention relates to a while-drilling sound wave automatic tracking wellbore tool and a use method thereof, the tool comprises a power generation and communication system comprising a power generation system and a communication system, the communication system is used for bidirectional transmission of measured data and control instructions; the power and measurement and control system comprises a measurement-while-drilling system, and the measurement-while-drilling system is used for measuring well deviation and azimuth data of a newly-drilled well and transmitting the data to the communication system; and the sound wave measuring and guiding system comprises a sound emission and measurement and control system, and the sound emission and measurement and control system is used for emitting sound wave signals in a newly-drilled well, receiving return signals and transmitting the return signals to the communication system. The problems of communication from a new drilled well to an old well, real-time judgment of the distance between a drill bit and the old well and the like are solved, the sound emission and measurement and control system emits sound wave signals in the new drilled well, receives return signals and transmits the return signals to the communication system, the position of a wellbore is dynamically scanned and monitored in a sound wave while-drilling mode, and the purposes of while-drilling and while-measurement are achieved.

Description

Technical Field

[0001] This invention relates to the field of oil and gas extraction technology, and in particular to a drilling-while-drilling acoustic automatic tracking wellbore tool and its usage method. Background Technology

[0002] Currently, there are many old oil and gas fields, which provides a foundation for the large-scale construction of gas storage facilities. However, the old wells in some oilfield blocks are complex, with multiple branches, objects falling into the wellbore, casing deformation, and old wellhead collapses. A number of newly built gas storage facilities contain abandoned wells that are difficult to dispose of (with fish falling into the well), and side-drilling with directional drilling has been carried out. This means that the old wells cannot be treated through the original wellbore. These complex old wells have exposed the reservoir, which seriously affects the feasibility of constructing gas storage facilities with such wells.

[0003] As the development of old oilfields continues to deepen, the proportion of complex casing fault wells is increasing year by year, and the difficulty of repair is gradually increasing. According to statistics, complex casing fault wells are mainly those with misaligned casing without access channels. In severe cases, gas leakage inside and outside the casing and inter-layer gas flow may occur. There are no effective detection methods for this type of casing fault during well repair, making it impossible to find the missing casing, resulting in the inability to repair or effective abandonment, which seriously affects the injection and production relationship of the block. At the same time, this type of casing fault can cause the downhole fluid flow to carry shallow water back to the surface, causing serious environmental problems.

[0004] A common method in the drilling industry is to drill new wells along the trajectory of the old wellbore. This method requires maintaining directional accuracy so that the new wellbore trajectory always maintains a suitable distance from the old wellbore trajectory. The commonly used directional tool is a passive magnetic directional tool, which can capture the magnetic signal of the casing of the old wellbore. Through signal analysis and processing, the real-time relative position of the new wellbore and the old wellbore is calculated, providing reliable parameters for the next step of directional drilling. In the early stage of drilling, measurements are taken every 50-100 meters, and in the later stage, measurements are taken every 5-20 meters, or even every 1 meter. This involves multiple trips in and out of the drill string, which is inefficient. At the same time, existing tools cannot drill into old wellbores with casing at the bottom.

[0005] The conventional approach to solving this problem is to perforate the old wellbore through a new wellbore to penetrate the casing of the old wellbore, and then squeeze cement slurry into the old wellbore to seal it. However, this method of perforating the old wellbore and then squeezing in cement slurry for sealing has great uncertainty and cannot guarantee the sealing performance of the old wellbore. At the same time, this method cannot achieve the reuse of the lower casing after well failure and bridging.

[0006] The best approach is to use sonic probes to determine the distance and orientation of the old wellbore during new drilling. Based on the measurements, the wellbore trajectory is adjusted to approach the old wellbore using a measurement-while-drilling (MWD) system and control system. If there is casing at the bottom, the measurement and control system is used to gradually approach the casing until a window is opened outside the casing, allowing the old wellbore to be re-entered. Cement slurry is then injected for sealing. This method ensures effective sealing of the caprock in old wellbores in environmental remediation wells and gas storage facilities. If there is remaining oil in the lower part of the casing-broken well, expansion pipe bridging is used to achieve wellbore reconstruction and reuse.

[0007] Currently, existing windowing technologies and processes are difficult to implement when facing the construction challenges of opening windows outside the pipe and re-entering old wells. Furthermore, the position of the drill bit during the construction process can easily lead to failure to drill into or out of the wellbore. Therefore, it is necessary to explore a new tool, new technology, and new method to solve construction problems such as connecting new and old wells and real-time monitoring of drill bit distance, so as to achieve efficient sealing of old wells and wellbore reconstruction, and achieve the goals of safe gas storage construction, environmental well remediation, and residual oil extraction from broken wells.

[0008] The tools and methods for real-time measurement of wellbore using acoustic drilling are still lacking. Existing windowing techniques and processes are inefficient, making it difficult to implement external windowing and re-entry into old wellbores. Furthermore, it's difficult to determine whether drilling has commenced or exited when the lower part is a cement plug or open hole. Therefore, it is necessary to explore new tools, technologies, and methods to solve problems such as connecting new wells to old wellbores and real-time determination of the drill bit's distance from the old wellbore. This would enable efficient sealing of old wellbores or wellbore reconstruction, achieving goals such as safe gas storage construction, environmental well remediation, and residual oil extraction from wells with casing failures.

[0009] Therefore, based on years of experience and practice in related industries, the inventor proposes a drilling-while-drilling acoustic automatic tracking wellbore tool and its usage method to overcome the shortcomings of existing technologies. Summary of the Invention

[0010] The purpose of this invention is to provide a drilling-while-drilling acoustic automatic tracking wellbore tool and its usage method, which effectively solves problems such as the connection between the new well and the old wellbore and the real-time judgment of the distance between the drill bit and the old wellbore. In this invention, an acoustic emission and measurement and control system emits acoustic signals in the new wellbore, receives return signals, and transmits the return signals to the communication system. Through the acoustic drilling-while-drilling method, the wellbore position is dynamically scanned and monitored to achieve the purpose of drilling and measurement.

[0011] The objective of this invention is achieved by providing an automatic acoustic tracking wellbore tool while drilling, comprising the following sequentially configured components:

[0012] The power generation and communication system includes a power generation system and a communication system electrically connected to a ground control center. The power generation system is used to generate electricity and supply power, and the communication system is used for bidirectional transmission of measurement data and control commands.

[0013] The power and measurement and control system includes a measurement while drilling system, a power motor, and a measurement and control system. The measurement while drilling system is used to measure the wellbore inclination and azimuth data of the newly drilled well and transmit the data to the communication system. The power motor is used to convert the hydraulic energy of the drilling mud into mechanical energy. The measurement and control system includes a control and communication electronic cabin that is electrically connected to the communication system.

[0014] The acoustic wave measurement and guidance system includes an acoustic emission and control system, a guidance system, and a transmission system. The acoustic emission and control system is used to emit acoustic signals in the new wellbore, receive return signals, and transmit the return signals to the communication system. The transmission system is used to transmit the mechanical energy of the power motor to the drill bit. The guidance system, under the control of the control and communication electronic cabin, automatically guides the system against the well wall to adjust the wellbore trajectory.

[0015] In a preferred embodiment of the present invention, the power generation system includes a pulse generator, a turbine assembly, and a generator. The turbine assembly and the generator are mounted on the pulse generator. The turbine assembly can drive the pulse generator to rotate under the action of mud. The rotation of the pulse generator causes the generator to generate electricity. The generator is electrically connected to the power and control system and the acoustic wave measurement and guidance system. The communication system includes a two-way communication electronic cabin. The generator is electrically connected to the two-way communication electronic cabin. The two-way communication electronic cabin is used for two-way communication between the power and control system, the acoustic wave measurement and guidance system, and the ground control center.

[0016] In a preferred embodiment of the present invention, the acoustic emission and control system includes an acoustic transmitter and receiver electrically connected to the two-way communication electronic cabin. The acoustic transmitter and receiver are used to emit acoustic signals in the new wellbore, receive return signals, and transmit the return signals to the two-way communication electronic cabin.

[0017] In a preferred embodiment of the present invention, the guiding system includes a push-fit structure and a push-fit motor, the push-fit motor being electrically connected to the two-way communication electronic cabin, the push-fit structure including a push-fit block, and the push-fit motor being able to drive the push-fit block to extend radially out of the push-fit well wall.

[0018] In a preferred embodiment of the present invention, the power motor includes a motor housing, a motor stator, and a motor rotor; the transmission system includes a universal joint, a water cap, and a drive shaft; the universal joint is fixedly connected to the motor rotor; the universal joint is connected to the drive shaft through the water cap; and the drive shaft is connected to the drill bit; the motor rotor drives the universal joint, the water cap, the drive shaft, and the drill bit to rotate under the action of the hydraulic energy of the mud.

[0019] In a preferred embodiment of the present invention, the power generation and communication system is disposed within a first housing, the measurement-while-drilling system is a gyroscope system, the gyroscope system includes a gyroscope housing, the first housing is connected to the gyroscope housing via a flexible short-circuit; the gyroscope housing is connected to the power motor via an anti-drop short-circuit structure; the end of the motor housing away from the gyroscope system is connected to a second housing and a third housing, the control and communication electronics compartment is disposed on the second housing, the acoustic emission and measurement and control system and the guidance system are disposed on the third housing, and the transmission system passes through the second housing and the third housing and is connected to the drill bit.

[0020] In a preferred embodiment of the present invention, the anti-drop short-circuit structure includes an anti-drop outer shell, a fourth central hole arranged axially inside the anti-drop outer shell, and a stop step portion arranged inside the fourth central hole; an anti-drop tie rod is arranged inside the fourth central hole, and the anti-drop tie rod and the fourth central hole are radially spaced to form a third flow channel annulus, the annulus between the motor stator and the motor rotor is connected to the third flow channel annulus; one end of the anti-drop tie rod away from the drilling gyroscope system is connected to the motor rotor, and the other end of the anti-drop tie rod is connected to an anti-drop nut, the anti-drop nut being axially stopped and prevented from falling off by the stop step portion.

[0021] In a preferred embodiment of the present invention, a fifth central hole is provided axially through the second housing; a sixth central hole is provided axially through the third housing; a fourth flow channel annulus is formed by a radial gap between the universal joint and the second housing, and the annulus between the motor stator and the motor rotor is connected to the fourth flow channel annulus; a third flow channel hole is provided on the water cap, connecting the fourth flow channel annulus and the sixth central hole, and the sixth central hole is connected to the drill bit water eye; the annulus between the motor stator and the motor rotor, the fourth flow channel annulus, the third flow channel hole and the sixth central hole are connected to form a mud flow channel.

[0022] In a preferred embodiment of the present invention, the end of the third housing near the drill bit is connected to a lower short-circuit for end sealing and limiting; a third TC bearing and a second string of bearings are provided between the drive shaft and the third housing, and a second string of bearing spacer and a second string of bearing sheath are provided between the second string of bearings and the lower short-circuit; a lower moving sleeve is provided between the lower short-circuit and the drive shaft.

[0023] In a preferred embodiment of the present invention, a plurality of first mounting slots are provided on the side wall of the third housing, and a pushing structure and a pushing motor are respectively embedded in each of the first mounting slots; a plurality of second mounting slots are also provided on the side wall of the third housing, and an acoustic transmitter and receiver are respectively embedded in each of the second mounting slots.

[0024] In a preferred embodiment of the present invention, a first central hole is provided axially through the first housing; the outer wall of the pulser is radially spaced from the inner wall of the first central hole; the turbine assembly and the generator are disposed between the pulser and the first housing; the end of the first housing away from the flexible short-circuit is connected to the upper connector of the pulser; a first TC bearing is provided between the end face of the upper connector of the pulser and the first axial end of the turbine assembly; a turbine sleeve, a turbine spacer, and a second TC bearing are provided between the second axial end of the turbine assembly and the first axial end of the generator; and a first string of bearings, a first string of bearing spacer, and a first string of bearing sleeve are provided between the second axial end of the generator and the end face of the flexible short-circuit.

[0025] A first flow channel annulus is provided between the upper connector of the pulser and the pulser itself. A first flow channel hole is axially provided through the first TC bearing. A second flow channel annulus is formed by a radial spacing between the turbine sleeve and the turbine spacer. A pulser blind hole is provided inside the pulser from one end near the flexible short joint inward. A second flow channel hole is provided on the side wall of the pulser, connecting the second flow channel annulus and the pulser blind hole. A second center hole is axially provided through the flexible short joint. A third center hole is axially provided through the gyroscope outer shell.

[0026] The first flow channel annulus, the first flow channel hole, the turbine assembly, the second flow channel annulus, the second flow channel hole, the pulser blind hole, the second center hole, the third center hole, and the fourth center hole are connected to form the upper flow channel of the mud.

[0027] In a preferred embodiment of the present invention, the bidirectional communication electronic compartment is disposed within the side wall of the first housing, and the generator is electrically connected to the bidirectional communication electronic compartment via a power supply channel to supply power to it; the control and communication electronic compartment is disposed within the side wall of the second housing, and a communication and power supply channel is provided through the side walls of the first housing, the flexible short circuit, the gyroscope housing, the anti-drop housing, the motor housing, and the second housing, and the bidirectional communication electronic compartment is electrically connected to the control and communication electronic compartment via the communication and power supply channel; an acoustic emission and support block control channel is disposed within the side wall of the third housing, and the control and communication electronic compartment is electrically connected to the push motor and the acoustic emission and receiver via the acoustic emission and support block control channel.

[0028] The objective of this invention can also be achieved by providing a method for using a drilling-while-drilling acoustic automatic tracking wellbore tool, comprising the following steps:

[0029] Step a: Connect the drill string, the sonic logging tool, and the drill bit, and lower them into the well.

[0030] Step b: Transmit acoustic signals in all directions through acoustic emission and receiver in the new wellbore;

[0031] Step c: Acoustic emission and receiver receiving of the returned signal;

[0032] Step d: Measure the inclination and azimuth of the new wellbore using the gyroscope system while drilling;

[0033] Step e: Transmit the relevant measurement data to the ground control center via mud pulses, and interpret and analyze the relative distance and orientation between the old wellbore and the new wellbore;

[0034] Step f: Based on the measurement data, the ground control center sends instructions to the two-way communication electronic cabin, which then transmits the instructions to the control and communication electronic cabin.

[0035] Step g: The pusher motor at the required orientation drives the pusher block in the pusher structure to push against the well wall.

[0036] Step h: Adjust the wellbore trajectory in real time based on the measurement results;

[0037] Step i: Enter the lower part of the wellbore of the old well.

[0038] As described above, the automatic acoustic tracking wellbore tool and its usage method provided by the present invention have the following beneficial effects:

[0039] In this invention, an acoustic emission and measurement and control system emits acoustic signals in the new wellbore, receives return signals, and transmits the return signals to the communication system, achieving the purpose of drilling and measurement while drilling, accurately locating broken casing, fallen fish, cement plugs, etc. in the lower wellbore; this invention can enter the lower wellbore, and by controlling the push and pull of the lower guide system, it can achieve 360° automatic adjustment of the tool face angle to complete the guidance. According to the distance and orientation of the wellbore detected by acoustic waves, the drilling attitude is adjusted in real time to achieve the purpose of re-entering the old wellbore. Finally, according to the needs of the site, it can be plugged or expanded tube bridging can be used for reuse.

[0040] This invention solves technical problems such as the treatment of difficult wells in gas storage facilities, the management of environmental protection wells, and the reuse of wells with casing defects. In terms of ballast engineering in old oilfields, it enables well network reconstruction, significantly improving the potential tapping of remaining oil and achieving the goal of stable crude oil production. In terms of gas storage facility construction, it makes it possible to build gas storage facilities in areas with a large number of difficult old wells that could not be effectively treated in the past, thus ensuring energy security. In terms of environmental protection well management, it enables re-entry into old wellbores and complete sealing of wells with casing defects in the lower part of the casing, solving the problem of environmental protection well management that has plagued oilfields for many years. Attached Figure Description

[0041] The accompanying drawings are intended only to illustrate and explain the present invention and do not limit the scope of the invention.

[0042] in:

[0043] Figure 1 This is a schematic diagram of the structure of the automatic acoustic tracking wellbore tool for drilling according to the present invention.

[0044] Figure 2 This is a schematic diagram of the upper connector of the pulser of the present invention.

[0045] Figure 3 This is a schematic diagram of the first TC bearing of the present invention.

[0046] Figure 4 for Figure 3 Sectional view of AA.

[0047] Figure 5 This is a schematic diagram of the turbine assembly of the present invention.

[0048] Figure 6 This is a schematic diagram of the connection between the first housing and the flexible joint of the present invention.

[0049] Figure 7 This is a schematic diagram of the automatic acoustic tracking wellbore tool for detecting the lower cavity during drilling, as described in this invention.

[0050] Figure 8 This is a schematic diagram of the automatic acoustic tracking wellbore tool for detecting broken casing in the lower part of the casing according to the present invention.

[0051] Figure 9 This is a schematic diagram of the automatic acoustic tracking wellbore tool for detecting fish in the lower part of the well.

[0052] Figure 10 A schematic diagram for detecting the positional relationship between old and new wellbores.

[0053] Figure 11 This is a partial schematic diagram of the pushing block of the pushing structure of the present invention.

[0054] Figure 12 This is a flowchart of the automatic acoustic tracking wellbore method while drilling according to the present invention.

[0055] In the picture:

[0056] 100. Power generation and communication system; 200. Power and measurement and control system; 300. Acoustic wave measurement and guidance system; 400. Ground control center;

[0057] 1. Upper connector of the pulse generator; 101. Connector slot; 102. First flow channel annulus;

[0058] 2. Pulse generator; 201. Second flow channel orifice;

[0059] 3. First shell;

[0060] 4. First TC bearing stationary sleeve; 401. First flow channel bore;

[0061] 5. First TC bearing moving sleeve;

[0062] 6. Turbine assembly;

[0063] 7. Turbine bushing;

[0064] 8. Turbine bushing;

[0065] 9. Second TC bearing stationary sleeve;

[0066] 10. Second TC bearing moving sleeve;

[0067] 11. Generator;

[0068] 12. Power supply channel;

[0069] 13. Two-way communication electronic cabin;

[0070] 14. The first set of bearings;

[0071] 15. First string of bearing spacers;

[0072] 16. First string of bearing sleeves;

[0073] 17. Communication and power supply channels;

[0074] 18. Circuit connection ring;

[0075] 19. Flexible short circuit;

[0076] 20. Drilling while gyroscope system;

[0077] 21. Prevents the outer casing from falling off;

[0078] 22. Prevent nuts from falling off;

[0079] 23. Anti-drop lever;

[0080] 24. Motor stator;

[0081] 25. Motor rotor;

[0082] 26. Universal joint;

[0083] 27. Second shell;

[0084] 28. Control and Communications Electronics Module;

[0085] 29. Water cap; 2901. Third flow channel orifice;

[0086] 30. Acoustic emission and support block control channel;

[0087] 31. Push against the motor;

[0088] 32. Third TC bearing stationary sleeve;

[0089] 33. Third TC bearing moving sleeve;

[0090] 34. Push-and-hold structure;

[0091] 35. The second set of bearings;

[0092] 36. Third shell;

[0093] 37. Acoustic emission and receiver;

[0094] 38. Short circuit at the bottom;

[0095] 39. Lowering the sleeve;

[0096] 40. Drive shaft;

[0097] 41. Drill bit; 4101. Drill bit water inlet;

[0098] 42. Old wellhead;

[0099] 43. Upper sleeve;

[0100] 44. Lower cavity;

[0101] 45. New wellbore;

[0102] 46. ​​Lower sleeve breakage; 4601. Sleeve breakage fish head;

[0103] 47. Falling fish. Detailed Implementation

[0104] To provide a clearer understanding of the technical features, objectives, and effects of the present invention, specific embodiments of the present invention will now be described with reference to the accompanying drawings.

[0105] The specific embodiments of the present invention described herein are for illustrative purposes only and should not be construed as limiting the invention in any way. Under the teachings of this invention, those skilled in the art can conceive of any possible modifications based on the invention, all of which should be considered within the scope of the invention. It should be noted that when an element is referred to as being "set on" another element, it can be directly on the other element or there may be an intervening element. When an element is referred to as being "connected" to another element, it can be directly connected to the other element or there may be an intervening element. The terms "mounted," "connected," and "linked" should be interpreted broadly; for example, they can refer to mechanical or electrical connections, or internal communication between two elements, and can be direct or indirect connections through an intermediate medium. Those skilled in the art can understand the specific meaning of the above terms according to the specific circumstances. The terms "vertical," "horizontal," "upper," "lower," "left," "right," and similar expressions used herein are for illustrative purposes only and do not represent the only possible embodiments.

[0106] Unless otherwise defined, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this application belongs. The terminology used herein is for the purpose of describing particular embodiments only and is not intended to be limiting of the application. The term "and / or" as used herein includes any and all combinations of one or more of the associated listed items.

[0107] like Figures 1 to 6 As shown, the present invention provides an automatic acoustic tracking wellbore tool while drilling, comprising the following sequentially arranged components:

[0108] The power generation and communication system 100 includes a power generation system and a communication system electrically connected to the ground control center 400. The power generation system is used to generate electricity and supply power, and the communication system is used for bidirectional transmission of measurement data and control commands.

[0109] The power and measurement and control system 200 includes a measurement while drilling system, a power motor, and a measurement and control system. The measurement while drilling system is used to measure the inclination and azimuth data of the newly drilled well and transmit the data to the communication system. The power motor is used to convert the hydraulic energy of the drilling mud into mechanical energy. The measurement and control system includes a control and communication electronic compartment 28 that is electrically connected to the communication system.

[0110] The acoustic measurement and guidance system 300 includes an acoustic emission and control system, a guidance system, and a transmission system. The acoustic emission and control system is used to emit acoustic signals in the new wellbore, receive return signals, and transmit the return signals to the communication system. The transmission system is used to transmit the mechanical energy of the power motor to the drill bit. The guidance system automatically guides itself against the well wall under the control of the control and communication electronic cabin to adjust the wellbore trajectory.

[0111] This invention provides power to the communication system, power and measurement and control system 200, and acoustic wave measurement and guidance system 300 through a self-generated power generation system. At the same time, it uses a pulser to transmit signals to the ground control center through mud pulses. By interpreting and analyzing relevant data such as acoustic waves and gyroscopes, and adjusting according to the existing wellbore trajectory, it sends commands downhole to control and adjust the drill string attitude to drill towards the target position.

[0112] In the automatic acoustic tracking wellbore tool of this invention, acoustic wave signals are emitted in the new wellbore through an acoustic emission and measurement and control system, and the return signals are received and transmitted to the communication system to achieve the purpose of drilling and measurement, accurately locating broken casing, fallen fish, cement plugs, etc. in the lower wellbore. This invention can enter the lower wellbore and achieve 360° automatic adjustment of the tool face angle to complete the guidance by controlling the push and pull of the lower guide system. According to the distance and orientation of the wellbore detected by acoustic waves, the drilling attitude is adjusted in real time to achieve the purpose of re-entering the old wellbore. Finally, according to the needs of the site, it can be used for plugging or expansion tube bridging and reuse.

[0113] This invention solves technical problems such as the treatment of difficult wells in gas storage facilities, the management of environmental protection wells, and the reuse of wells with casing defects. In terms of ballast engineering in old oilfields, it enables well network reconstruction, significantly improving the potential tapping of remaining oil and achieving the goal of stable crude oil production. In terms of gas storage facility construction, it makes it possible to build gas storage facilities in areas with a large number of difficult old wells that could not be effectively treated in the past, thus ensuring energy security. In terms of environmental protection well management, it enables re-entry into old wellbores and complete sealing of wells with casing defects in the lower part of the casing, solving the problem of environmental protection well management that has plagued oilfields for many years.

[0114] Furthermore, such as Figure 1 As shown, the power generation system includes a pulse generator 2, a turbine assembly 6, and a generator 11. The turbine assembly 6 and the generator 11 are mounted on the pulse generator 2. The turbine assembly 6 can drive the pulse generator 2 to rotate under the action of mud. The rotation of the pulse generator 2 causes the generator 11 to generate electricity. The generator 11 is electrically connected to the power and measurement and control system 200 and the acoustic wave measurement and guidance system 300. The communication system includes a two-way communication electronic cabin 13. The generator 11 is electrically connected to the two-way communication electronic cabin 13 (a battery pack is installed inside the cabin for storing electrical energy). The two-way communication electronic cabin 13 is used for two-way communication between the power and measurement and control system 200, the acoustic wave measurement and guidance system 300, and the ground control center 400.

[0115] Furthermore, such as Figure 1 As shown, the acoustic emission and control system includes an acoustic transmitter and receiver 37 electrically connected to the two-way communication electronic cabin 13. The acoustic transmitter and receiver 37 is used to emit acoustic signals in the new wellbore, receive return signals, and transmit the return signals to the two-way communication electronic cabin 13.

[0116] Furthermore, such as Figure 1As shown, the guidance system includes a push-fit structure 34 and a push-fit motor 31. The push-fit motor 31 is electrically connected to the two-way communication electronic cabin 13. The push-fit structure 34 includes a push-fit block. The push-fit motor 31 can drive the push-fit block to extend radially out of the push-fit well wall.

[0117] Furthermore, such as Figure 1 As shown, the power motor includes a motor housing, a motor stator 24, and a motor rotor 25. The transmission system includes a universal joint 26, a water cap 29, and a drive shaft 40. The universal joint 26 is fixedly connected to the motor rotor 25. The universal joint 26 is connected to the drive shaft 40 through the water cap 29. The drive shaft 40 is connected to the drill bit 41. Under the action of the hydraulic energy of the mud, the motor rotor 25 drives the universal joint 26, the water cap 29, the drive shaft 40, and the drill bit 41 to rotate.

[0118] The power motor can convert the hydraulic energy of the mud into mechanical energy, which is transmitted to the drill bit 41 through the universal joint 26 and the drive shaft 40. Since the motor rotor 25 rotates eccentrically around the motor stator 24, the universal joint 26 converts the eccentric motion into the directional rotation of the drive shaft 40. The universal joint 26 is made of a certain degree of flexibility, and the material includes, but is not limited to, titanium alloy, beryllium copper alloy, etc.

[0119] Furthermore, the power generation and communication system is located inside the first housing 3. If the distance to the casing is less than 5 meters, a drilling gyroscope (serial number 20) is used to reduce interference. If the distance to the casing is greater than 5 meters, a MWD (Measurement While Drilling) system can be used. The measurement while drilling system is a drilling gyroscope system 20. The drilling gyroscope system 20 includes a gyroscope housing. The first housing 3 is connected to the gyroscope housing via a flexible short circuit 19. The gyroscope housing is connected to a power motor via an anti-drop short circuit structure. The end of the motor housing away from the drilling gyroscope system 20 is connected to the second housing 27 and the third housing 36. The control and communication electronics compartment 28 is located on the second housing 27. The acoustic emission and measurement and control system and the guidance system are located on the third housing 36. The transmission system passes through the second housing 27 and the third housing 36 and is connected to the drill bit 41.

[0120] When the flexible short connector 19 pushes the well wall via the push block extending from the lower push structure 34, it undergoes bending deformation, achieving 360° automatic adjustment of the tool face angle and automatic guidance. Its material is titanium alloy, copper alloy, etc., possessing high strength and flexibility.

[0121] The second housing 27 is a protective housing for components such as the universal joint 26 and the control and communication electronic compartment 28; the water cap 29 is used to connect the universal joint 26 and the drive shaft 40, and its surface has a third flow channel hole 2901 (water cap flow channel); the third housing 36 is a protective housing for components such as the push-back structure 34, the acoustic transmitter and receiver 37, and the drive shaft 40.

[0122] Furthermore, such as Figure 1As shown, the anti-drop short-circuit structure includes an anti-drop housing 21, with a fourth central hole axially arranged inside the housing 21. A stop step is provided within the fourth central hole. An anti-drop pull rod 23 is installed within the fourth central hole, and the anti-drop pull rod 23 and the fourth central hole are radially spaced to form a third flow channel annulus. The annulus between the motor stator 24 and the motor rotor 25 communicates with the third flow channel annulus. One end of the anti-drop pull rod 23, away from the drilling gyroscope system 20, is connected to the motor rotor 25, and the other end is connected to an anti-drop nut 22. The anti-drop nut 22 can be axially stopped by the stop step to prevent it from falling off. When the lower shaft breaks, the anti-drop nut 22 is locked at the stop step inside the anti-drop short-circuit, thus preventing it from falling off.

[0123] Furthermore, such as Figure 1 As shown, a fifth central hole is provided axially through the second housing 27; a sixth central hole is provided axially through the third housing 36; the universal joint and the second housing are radially spaced to form a fourth flow channel annulus, and the annulus between the motor stator 24 and the motor rotor 25 is connected to the fourth flow channel annulus; a third flow channel hole 2901 is provided on the water cap 29 to connect the fourth flow channel annulus and the sixth central hole, and the sixth central hole is connected to the drill bit water eye 4101 of the drill bit 41; the annulus between the motor stator and the motor rotor, the fourth flow channel annulus, the third flow channel hole and the sixth central hole are connected to form a mud flow channel.

[0124] Furthermore, such as Figure 1 As shown, the end of the third housing 36 near the drill bit 41 is connected to a lower shorting 38 for end sealing and limiting; a third TC bearing and a second string of bearings 35 are provided between the drive shaft 40 and the third housing 36, and a second string of bearing spacer and a second string of bearing sheath are provided between the second string of bearings 35 and the lower shorting 38; a lower moving sleeve 39 is provided between the lower shorting and the drive shaft.

[0125] The third TC bearing includes the third TC bearing stationary sleeve 32 and the third TC bearing moving sleeve 33. The third TC bearing stationary sleeve 32, the third TC bearing moving sleeve 33, the lower short joint 38 and the lower moving sleeve 39 function to radially straighten the drive shaft 40 and can withstand lateral forces. The second bearing 35 withstands drilling pressure and promotes the rotation of the drive shaft 40.

[0126] Furthermore, such as Figure 1 As shown, the third housing 36 has a plurality of first mounting slots on its side wall, and each first mounting slot is fitted with a push structure 34 and a push motor 31 respectively; the third housing 36 also has a plurality of second mounting slots on its side wall, and each second mounting slot is fitted with a sound transmitter and a receiver 37 respectively.

[0127] In a specific embodiment of the present invention, the push-back structure 34, the acoustic transmitter and receiver 37 are evenly embedded on the third housing 36, the push-back structure 34 and the push-back motor 31 are three sets, each set with an included angle of 60°, and the acoustic transmitter and receiver 37 can be 3-12 sets.

[0128] Furthermore, such as Figure 1 , Figure 2 As shown, a first central hole is provided axially through the first housing 3; the outer wall of the pulser 2 and the inner wall of the first central hole are radially spaced apart; the turbine assembly 6 and the generator 11 are disposed between the pulser 2 and the first housing 3; the end of the first housing 3 away from the flexible short-circuit 19 is connected to the upper connector 1 of the pulser, the upper connector 1 of the pulser is connected to the upper drill string, and a connector slot 101 is provided on the upper connector 1 of the pulser;

[0129] A first TC bearing (such as...) is provided between the end face of the upper connector 1 of the pulse generator and the first axial end of the turbine assembly 6. Figure 3 , Figure 4 As shown, it includes the first TC bearing stationary sleeve 4 and the first TC bearing moving sleeve 5, as... Figure 1 , Figure 5 As shown, a turbine sleeve 7, a turbine spacer 8, and a second TC bearing (including a second TC bearing stationary sleeve 9 and a second TC bearing moving sleeve 10) are provided between the second axial end of the turbine assembly 6 and the first axial end of the generator 11. Figure 6 As shown, a first string of bearings 14, a first string of bearing spacers 15, and a first string of bearing sheaths 16 are provided between the second axial end of the generator 11 and the end face of the flexible short circuit 19.

[0130] The first TC bearing is a radial bearing, which plays a radial alignment role when the turbine assembly 6 rotates at high speed. The contact surfaces of the first TC bearing stationary sleeve 4 and the first TC bearing moving sleeve 5 are inlaid with wear-resistant materials (including but not limited to hard alloy and PDC composite sheets), which can provide lubrication through a small amount of mud. The turbine sleeve 7 and the turbine spacer 8 axially position the turbine assembly 6. The second TC bearing stationary sleeve 9 and the second TC bearing moving sleeve 10 play a radial alignment role when the generator 11 rotates at high speed. The first string bearing 14 can promote the rotation of the generator 11. The first string bearing spacer 15 and the first string bearing sleeve 16 radially limit the first string bearing 14 and the pulse generator 2.

[0131] like Figure 1 As shown, a first flow channel annulus 102 is provided between the upper connector 1 and the pulser 2. A first flow channel hole 401 is axially provided on the first TC bearing. A second flow channel annulus is formed by radial spacing between the turbine sleeve 7 and the turbine spacer 8. A pulser blind hole is provided inside the pulser 2 from one end near the flexible short connector inward. A second flow channel hole 201 is provided on the side wall of the pulser 2, connecting the second flow channel annulus and the pulser blind hole. A second center hole is axially provided inside the flexible short connector 19. A third center hole is axially provided inside the gyroscope outer shell.

[0132] The first flow channel annulus 102, the first flow channel hole 401, the turbine assembly 6, the second flow channel annulus, the second flow channel hole 201, the pulser blind hole, the second center hole, the third center hole and the fourth center hole are connected to form the upper flow channel of the mud.

[0133] The mud flow channel (the upper mud flow channel and the lower mud flow channel are connected) is as follows: drill string center hole (existing technology) → first flow channel annulus 102 → first flow channel hole 401 → turbine assembly 6 → second flow channel annulus → second flow channel hole 201 → pulser blind hole → second center hole → third center hole → fourth center hole → annulus between motor stator and motor rotor → fourth flow channel annulus → third flow channel hole → sixth center hole → drill bit water hole 4101. After returning to the surface through the drill string and wellbore annulus, it is filtered and recycled.

[0134] Furthermore, such as Figure 1 As shown, the two-way communication electronic compartment 13 is located inside the side wall of the first housing 3. The generator 11 is electrically connected to the two-way communication electronic compartment 13 through the power supply channel 12 to supply power to it. The control and communication electronic compartment 28 is located inside the side wall of the second housing 27. The communication and power supply channel 17 is arranged through the side wall of the first housing 3, the flexible short circuit 19, the gyroscope housing, the anti-drop housing 21, the motor housing, and the second housing 27. The two-way communication electronic compartment 13 is electrically connected to the control and communication electronic compartment 28 through the communication and power supply channel 17. The acoustic emission and support block control channel 30 is provided inside the side wall of the third housing 36. The control and communication electronic compartment 28 is electrically connected to the push motor 31 and the acoustic emission and receiver 37 through the acoustic emission and support block control channel 30. Each housing section is connected by threads; at the threaded connection, each section of the communication and power supply channel 17 is electrically connected by a circuit connection ring 18.

[0135] The power supply and communication pathways of the present invention are as follows: turbine assembly 6 → generator 11 → power supply channel 12 → two-way communication electronic compartment 13 ←→ ←→ communication and power supply channel 17 ←→ control and communication electronic compartment 28 ←→ acoustic emission and support block control channel 30 ←→ push motor 31 ←→ acoustic emission and receiver 37.

[0136] In use, the upper part of the pulser connector 1 is connected to the drill string via threads. Mud enters the first flow channel annulus 102 through the drill string's central hole and then enters the turbine assembly 6 through the first flow channel hole 401. The turbine assembly's rotation drives the pulser's main shaft to rotate, generating current through the generator's rotor. This current powers the bidirectional communication electronic compartment 13 via the power supply channel 12. The bidirectional communication electronic compartment 13 powers and transmits signals to the control and communication electronic compartment 28, the pusher motor 31, and the acoustic transmitter and receiver 37 via the communication and power supply channel 17, the circuit connection ring 18, and the acoustic emission and support block control channel 30. The bidirectional communication electronic compartment 13 can transmit data from the drilling gyroscope system 20 and the acoustic transmitter and receiver 37 to the ground control center 400, and can also transmit relevant commands from the ground control center 400 to the control and communication electronic compartment 28, controlling the opening of the pusher block in the pusher structure 34. The pusher structure 34 pushes against the well wall, causing the flexible shorting joint 19 to bend and deform, achieving automatic guidance.

[0137] This invention provides a method for using a drilling-while-drilling acoustic automatic tracking wellbore tool, comprising the following steps (flowchart shown below). Figure 12 As shown):

[0138] Step a: Connect the drill string, the sonic logging tool, and the drill bit, and lower them into the well.

[0139] Step b: Transmit acoustic signals in all directions through acoustic transmitter and receiver 37 in the new wellbore;

[0140] A schematic diagram of the present invention for detecting the lower cavity 44 (or cement plug) is shown below. Figure 7 The schematic diagram of the detection of the lower sleeve breakage 46 of the present invention is shown below. Figure 8 This includes an upper sleeve 43, a lower sleeve 46, and a sleeve head 4601; a schematic diagram of the present invention for detecting fish falling from the lower part of the sleeve 47 is shown below. Figure 9 .

[0141] Step c: Acoustic transmitter and receiver 37 receives the return signal;

[0142] Step d: The drilling gyroscope system 20 measures the inclination and azimuth of the new wellbore;

[0143] Step e: Transmit the relevant measurement data to the ground control center 400 via mud pulses, and interpret and analyze the relative distance and azimuth between the old wellbore 42 and the new wellbore 45. The cross-section is shown below. Figure 10 As shown;

[0144] The analytical calculation formula used is:

[0145] Where D is the relative distance between the old wellbore 42 and the new wellbore 45, d is the diameter of the old wellbore 42, α is the minimum angle between the old wellbore and the new wellbore and the due north (N) direction, and β is the maximum angle between the old wellbore and the new wellbore and the due north (N) direction.

[0146] Step f: Based on the measurement data, the ground control center 400 sends instructions to the two-way communication electronic cabin 13, and the two-way communication electronic cabin 13 transmits the instructions to the control and communication electronic cabin 28.

[0147] Step g: The pusher motor 31 at the required orientation drives the pusher block in the pusher structure 34 to push against the well wall, as shown. Figure 11 As shown;

[0148] Step h: Adjust the wellbore trajectory in real time based on the measurement results;

[0149] Step i: Enter the lower part of the wellbore of the old well.

[0150] As described above, the automatic acoustic tracking wellbore tool and its usage method provided by the present invention have the following beneficial effects:

[0151] In this invention, an acoustic emission and measurement and control system emits acoustic signals in the new wellbore, receives return signals, and transmits the return signals to the communication system, achieving the purpose of drilling and measurement while drilling, accurately locating broken casing, fallen fish, cement plugs, etc. in the lower wellbore; this invention can enter the lower wellbore, and by controlling the push and pull of the lower guide system, it can achieve 360° automatic adjustment of the tool face angle to complete the guidance. According to the distance and orientation of the wellbore detected by acoustic waves, the drilling attitude is adjusted in real time to achieve the purpose of re-entering the old wellbore. Finally, according to the needs of the site, it can be plugged or expanded tube bridging can be used for reuse.

[0152] This invention solves technical problems such as the treatment of difficult wells in gas storage facilities, the management of environmental protection wells, and the reuse of wells with casing defects. In terms of ballast engineering in old oilfields, it enables well network reconstruction, significantly improving the potential tapping of remaining oil and achieving the goal of stable crude oil production. In terms of gas storage facility construction, it makes it possible to build gas storage facilities in areas with a large number of difficult old wells that could not be effectively treated in the past, thus ensuring energy security. In terms of environmental protection well management, it enables re-entry into old wellbores and complete sealing of wells with casing defects in the lower part of the casing, solving the problem of environmental protection well management that has plagued oilfields for many years.

[0153] The above description is merely an illustrative embodiment of the present invention and is not intended to limit the scope of the invention. Any equivalent changes and modifications made by those skilled in the art without departing from the concept and principles of the present invention should fall within the scope of protection of the present invention.

Claims

1. A drilling-while-drilling acoustic automatic tracking wellbore tool, characterized in that, Including sequence settings: The power generation and communication system includes a power generation system and a communication system electrically connected to a ground control center. The power generation system is used to generate electricity and supply power, and the communication system is used for bidirectional transmission of measurement data and control commands. The power and measurement and control system includes a measurement while drilling system, a power motor, and a measurement and control system. The measurement while drilling system is used to measure the wellbore inclination and azimuth data of the newly drilled well and transmit the data to the communication system. The power motor is used to convert the hydraulic energy of the drilling mud into mechanical energy. The measurement and control system includes a control and communication electronic cabin that is electrically connected to the communication system. The acoustic wave measurement and guidance system includes an acoustic emission and control system, a guidance system, and a transmission system. The acoustic emission and control system is used to emit acoustic signals in the new wellbore, receive return signals, and transmit the return signals to the communication system. The transmission system is used to transmit the mechanical energy of the power motor to the drill bit. The guidance system, under the control of the control and communication electronic cabin, automatically guides the system against the well wall to adjust the wellbore trajectory.

2. The automatic acoustic tracking wellbore tool while drilling as described in claim 1, characterized in that, The power generation system includes a pulse generator, a turbine assembly, and a generator. The turbine assembly and the generator are mounted on the pulse generator. The turbine assembly drives the pulse generator to rotate under the action of mud. The rotation of the pulse generator causes the generator to generate electricity. The generator is electrically connected to the power and control system and the acoustic wave measurement and guidance system. The communication system includes a two-way communication electronic cabin. The generator is electrically connected to the two-way communication electronic cabin. The two-way communication electronic cabin is used for two-way communication between the power and control system, the acoustic wave measurement and guidance system, and the ground control center.

3. The automatic acoustic tracking wellbore tool while drilling as described in claim 2, characterized in that, The acoustic emission and control system includes an acoustic transmitter and receiver electrically connected to the two-way communication electronic cabin. The acoustic transmitter and receiver are used to emit acoustic signals in the new wellbore, receive return signals, and transmit the return signals to the two-way communication electronic cabin.

4. The automatic acoustic tracking wellbore tool while drilling as described in claim 3, characterized in that, The guiding system includes a push-fit structure and a push-fit motor. The push-fit motor is electrically connected to the two-way communication electronic cabin. The push-fit structure includes a push-fit block, and the push-fit motor can drive the push-fit block to extend radially out of the push-fit well wall.

5. The automatic acoustic tracking wellbore tool while drilling as described in claim 4, characterized in that, The power motor includes a motor housing, a motor stator, and a motor rotor. The transmission system includes a universal joint, a water cap, and a drive shaft. The universal joint is fixedly connected to the motor rotor. The universal joint is connected to the drive shaft through the water cap. The drive shaft is connected to the drill bit. Under the action of the hydraulic energy of the mud, the motor rotor drives the universal joint, the water cap, the drive shaft, and the drill bit to rotate.

6. The automatic acoustic tracking wellbore tool while drilling as described in claim 5, characterized in that, The power generation and communication system is housed within the first housing. The measurement-while-drilling system is the gyroscope system, which includes a gyroscope housing. The first housing is connected to the gyroscope housing via a flexible short-circuit. The gyroscope housing is connected to the power motor via an anti-drop short-circuit structure. The end of the motor housing furthest from the gyroscope system is connected to the second and third housings. The control and communication electronics compartment is located on the second housing. The acoustic emission and measurement and control system and the guidance system are located on the third housing. The transmission system passes through the second and third housings and is connected to the drill bit.

7. The automatic acoustic tracking wellbore tool while drilling as described in claim 6, characterized in that, The anti-drop short-circuit structure includes an anti-drop housing, a fourth central hole arranged axially inside the anti-drop housing, and a stop step portion arranged inside the fourth central hole; an anti-drop tie rod is arranged inside the fourth central hole, and the anti-drop tie rod and the fourth central hole are radially spaced to form a third flow channel annulus, and the annulus between the motor stator and the motor rotor is connected to the third flow channel annulus; one end of the anti-drop tie rod away from the drilling gyroscope system is connected to the motor rotor, and the other end of the anti-drop tie rod is connected to an anti-drop nut, which can be axially stopped and prevented from falling off by the stop step portion.

8. The automatic acoustic tracking wellbore tool while drilling as described in claim 7, characterized in that, A fifth central hole is provided axially through the second housing; a sixth central hole is provided axially through the third housing; the universal joint and the second housing are radially spaced to form a fourth flow channel annulus, and the annulus between the motor stator and the motor rotor is connected to the fourth flow channel annulus; a third flow channel hole is provided on the water cap, connecting the fourth flow channel annulus and the sixth central hole, and the sixth central hole is connected to the drill bit water eye; the annulus between the motor stator and the motor rotor, the fourth flow channel annulus, the third flow channel hole and the sixth central hole are connected to form a mud flow channel.

9. The automatic acoustic tracking wellbore tool while drilling as described in claim 7, characterized in that, The third housing is connected to a lower short-circuit for end sealing and limiting at one end; a third TC bearing and a second string of bearings are provided between the drive shaft and the third housing; a second string of bearing spacer and a second string of bearing sheath are provided between the second string of bearings and the lower short-circuit; a lower moving sleeve is provided between the lower short-circuit and the drive shaft.

10. The automatic acoustic tracking wellbore tool while drilling as described in claim 7, characterized in that, The third housing has a plurality of first mounting slots on its side wall, and each first mounting slot is respectively embedded with a pushing structure and a pushing motor; the third housing also has a plurality of second mounting slots on its side wall, and each second mounting slot is respectively embedded with an acoustic transmitter and receiver.

11. The automatic acoustic tracking wellbore tool while drilling as described in claim 7, characterized in that, A first central hole is provided axially through the first housing; the outer wall of the pulser is radially spaced from the inner wall of the first central hole; the turbine assembly and the generator are disposed between the pulser and the first housing; the end of the first housing away from the flexible short-circuit is connected to the upper connector of the pulser; a first TC bearing is provided between the end face of the upper connector of the pulser and the first axial end of the turbine assembly; a turbine sleeve, a turbine spacer, and a second TC bearing are provided between the second axial end of the turbine assembly and the first axial end of the generator; a first string of bearings, a first string of bearing spacers, and a first string of bearing sleeves are provided between the second axial end of the generator and the end face of the flexible short-circuit. A first flow channel annulus is provided between the upper connector of the pulser and the pulser itself. A first flow channel hole is axially provided through the first TC bearing. A second flow channel annulus is formed by a radial spacing between the turbine sleeve and the turbine spacer. A pulser blind hole is provided inside the pulser from one end near the flexible short joint inward. A second flow channel hole is provided on the side wall of the pulser, connecting the second flow channel annulus and the pulser blind hole. A second center hole is axially provided through the flexible short joint. A third center hole is axially provided through the gyroscope outer shell. The first flow channel annulus, the first flow channel hole, the turbine assembly, the second flow channel annulus, the second flow channel hole, the pulser blind hole, the second center hole, the third center hole, and the fourth center hole are connected to form the upper flow channel of the mud.

12. The automatic acoustic tracking wellbore tool while drilling as described in claim 7, characterized in that, The two-way communication electronic compartment is located inside the side wall of the first shell, and the generator is electrically connected to the two-way communication electronic compartment through a power supply channel to supply power to it. The control and communication electronic compartment is located inside the side wall of the second housing. A communication and power supply channel is provided through the first housing, the flexible short circuit, the gyroscope housing, the anti-drop housing, the motor housing, and the side wall of the second housing. The bidirectional communication electronic compartment is electrically connected to the control and communication electronic compartment through the communication and power supply channel. An acoustic emission and support block control channel is provided inside the side wall of the third housing. The control and communication electronic compartment is electrically connected to the push motor and the acoustic emission and receiver through the acoustic emission and support block control channel.

13. A method of using the automatic acoustic tracking wellbore tool as described in any one of claims 1 to 12, characterized in that, Includes the following steps: Step a: Connect the drill string, the sonic logging tool, and the drill bit, and lower them into the well. Step b: Transmit acoustic signals in all directions through acoustic emission and receiver in the new wellbore; Step c: Acoustic emission and receiver receiving of the returned signal; Step d: Measure the inclination and azimuth of the new wellbore using the gyroscope system while drilling; Step e: Transmit the relevant measurement data to the ground control center via mud pulses, and interpret and analyze the relative distance and orientation between the old wellbore and the new wellbore; Step f: Based on the measurement data, the ground control center sends instructions to the two-way communication electronic cabin, which then transmits the instructions to the control and communication electronic cabin. Step g: The pusher motor at the required orientation drives the pusher block in the pusher structure to push against the well wall. Step h: Adjust the wellbore trajectory in real time based on the measurement results; Step i: Enter the lower part of the wellbore of the old well.

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