A sub-sampling system based on acoustic wave wireless transmission

Abstract

The utility model relates to a kind of based on acoustic wireless transmission's separate production system, system includes ground controller and at least one downhole separate production instrument, downhole separate production instrument is connected in series in oil pipe, its structure shell is equipped with magnetostrictive transducer short section, circuit control short section and oil nozzle short section.Magnetostrictive transducer short section rigidity connection is in shell, converts electric signal into vibration acoustic wave, is transmitted to ground through oil pipe wall, and receives the downlink instruction signal of ground;Circuit control short section integrates control chip and multiple sensors, for data acquisition and instruction processing;Oil nozzle short section adjusts the flow of this layer liquid production passage according to instruction.The utility model uses oil pipe wall as acoustic transmission channel, realizes the stable long-distance two-way communication without cable, solves the problems of traditional cable system construction complexity, high cost and existing wireless technology signal fast attenuation, poor reliability, with compact structure, control precision, high reliability and the advantages of low operating cost.

Description

Technical Field

[0001] This utility model belongs to the field of petroleum stratified oil recovery technology, specifically relating to a stratified oil recovery system based on acoustic wireless transmission. Background Technology

[0002] In the process of refined well exploitation, oilfields pay particular attention to downhole data. Currently, downhole data is mainly acquired through two methods: wired transmission and wireless transmission. Wired transmission technology mainly includes cables and optical fibers. Due to reliability and cost considerations, optical fibers are rarely used in production wells, so cable transmission is currently the primary method. However, wired transmission technology is complex to construct, expensive, and the cables and accessories run with the tubing are easily damaged in the harsh downhole environment, leading to a decrease in overall system reliability. Wireless transmission technology is currently mainly based on pressure pulse and electromagnetic wave technologies. Pressure pulse technology generates signals through the pressure difference of injected water to achieve wireless transmission, but it has low transmission efficiency and a high error rate. In addition, the limited amount of data that can be transmitted cannot meet the field requirements for downhole data. Electromagnetic wave wireless transmission technology is difficult to promote and use in oilfields at present due to the complexity of the equipment, high cost, and high power consumption. Furthermore, electromagnetic wave technology is greatly affected by well conditions, and obtaining signals is difficult in the presence of equipment interference downhole and at the well site.

[0003] Existing oil well extraction systems generally suffer from short signal transmission distances and poor stability. They are not the most efficient in terms of cost and transmission efficiency. Therefore, a transmission system that can achieve both fast communication and significantly reduce costs is needed to meet the requirements of refined oil well extraction. Utility Model Content

[0004] To address the aforementioned problems in the existing technology, this utility model provides a data acquisition system based on acoustic wireless transmission. The technical problem to be solved by this utility model is achieved through the following technical solution: This invention provides a downhole data acquisition system based on acoustic wireless transmission, comprising: a surface controller and at least one downhole data acquisition unit; the surface controller is connected to the tubing via a wellhead device, used to generate and transmit downlink control command signals, and receive and process uplink data signals; multiple downhole data acquisition units are connected in series in the tubing, and interlayer isolation is achieved through packers; each downhole data acquisition unit includes a structural housing and a magnetostrictive transducer section, a circuit control section, and a nozzle section disposed within the structural housing; wherein, the magnetostrictive transducer section is rigidly connected to the structural housing. The body is used to receive the drive signal from the circuit control sub and generate vibration according to the drive signal to form the uplink data signal, which is coupled to the tubing wall for transmission to the ground; the magnetostrictive transducer sub is also used to detect the downlink control command signal transmitted by the tubing wall; the circuit control sub is electrically connected to the magnetostrictive transducer sub and the nozzle sub respectively, and is used to control the operation of the magnetostrictive transducer sub and the nozzle sub respectively; the nozzle sub is used to adjust the flow rate of the produced fluid in the formation according to the command signal from the circuit control sub.

[0005] In one embodiment of the present invention, the structural housing includes an upper connector, an outer protective tube, and a lower connector connected in sequence, and is provided with a flow pipe for this layer and flow pipes for other layers inside, forming mutually isolated liquid production channels for this layer and liquid production channels for other layers; an inlet is provided on the side wall of the lower connector, and the inlet is connected to the liquid production channel for this layer.

[0006] In one embodiment of this utility model, the flow tube in this layer and the flow tubes in other layers are arranged in parallel within the structural housing. The flow tube in this layer is connected to the liquid inlet and the oil nozzle section to form the liquid production channel in this layer, and the flow tubes in other layers form the liquid production channel in other layers.

[0007] In one embodiment of this utility model, the magnetostrictive transducer section includes: a counterweight, an induction coil, a super magnetostrictive rod, a stress spring, and an induction plate. The induction coil is arranged around the super magnetostrictive rod and electrically connected to the circuit control section. The stress spring is disposed at one end of the super magnetostrictive rod and is used to apply bias stress. The counterweight is disposed at the other end of the super magnetostrictive rod and is used for inertial counterweight. The induction plate is used to detect the downward control command signal transmitted by the oil pipe wall.

[0008] In one embodiment of this utility model, the magnetostrictive transducer section is rigidly connected to the upper connector via a sliding sleeve joint.

[0009] In one embodiment of this utility model, the circuit control section includes a control chip, and an internal pressure sensor, an external pressure sensor, and a temperature sensor, which are electrically connected to the control chip respectively; wherein, the internal pressure sensor is used to measure the pressure data inside the tubing, the external pressure sensor is used to measure the formation pressure data, and the temperature sensor is used to measure the formation temperature data.

[0010] In one embodiment of this utility model, the nozzle sub-section is used to control the flow area of ​​the produced liquid in the local formation according to the instruction signal of the circuit control sub-section, so as to adjust the flow rate and open or close the produced liquid channel of the local formation; the nozzle sub-section includes a motor, a transmission mechanism and a piston rod, the output end of the motor is connected to the piston rod through the transmission mechanism; the transmission mechanism includes a lead screw connected to the output end of the motor and a stroke bracket cooperating with the lead screw, and the piston rod is disposed on the stroke bracket; the control chip drives the piston rod to move axially by controlling the forward and reverse rotation of the motor, so as to change the position of the piston rod in the produced liquid channel of the local formation, thereby adjusting the flow rate and opening or closing the produced liquid channel of the local formation.

[0011] In one embodiment of this utility model, the oil nozzle section further includes a limit switch, which is electrically connected to the control chip and is used to detect the extreme position of the piston rod.

[0012] In one embodiment of this utility model, each of the downhole extraction instruments further includes a battery sub-section, which is used to supply power to the magnetostrictive transducer sub-section, the circuit control sub-section, and the nozzle sub-section, respectively.

[0013] In one embodiment of this utility model, the ground controller includes a ground control module, a ground transmitting system, and a ground receiving system. The ground control module is electrically connected to the ground transmitting system and the ground receiving system, respectively. The ground transmitting system is used to generate the downlink control command signal through vibration, and the ground receiving system is used to receive and parse the uplink data signal.

[0014] Compared with the prior art, the beneficial effects of this utility model are as follows: This invention relates to a sound wave wireless transmission-based wellbore system. It utilizes the tubing wall as a solid-state sound wave transmission channel and employs a structure where a magnetostrictive transducer section is rigidly connected to the tubing. This allows the sound wave signal to propagate along the metal tubing wall with low attenuation and high speed, achieving stable and reliable two-way wireless communication between the surface and wells thousands of meters underground. This system not only successfully eliminates reliance on cables, simplifying the tubing structure and operational procedures and significantly reducing construction costs and risks, but also solves the problems of rapid signal attenuation and insufficient transmission distance in traditional wireless technologies. Thus, it achieves rapid communication while significantly reducing transmission costs.

[0015] The above description is merely an overview of the technical solution of this utility model. In order to better understand the technical means of this utility model and to implement it in accordance with the contents of the specification, and to make the above and other objects, features and advantages of this utility model more apparent and understandable, preferred embodiments are described below in detail with reference to the accompanying drawings. Attached Figure Description

[0016] Figure 1 This is a schematic diagram of the structure of a sound wave wireless transmission-based data acquisition system provided in an embodiment of this utility model; Figure 2 This is a schematic diagram of the structure of the downhole extraction instrument provided in this embodiment of the utility model; Figure 3 This is a schematic diagram of the internal structure of the downhole extraction instrument provided in this embodiment of the utility model; Figure 4 This is a structural cross-sectional view of the downhole extraction instrument provided in this embodiment of the utility model; Figure 5 This is a working block diagram of the acoustic wireless transmission-based data acquisition system provided in this embodiment of the utility model.

[0017] Icons: 100-Ground controller; 110-Ground control module; 120-Ground transmitting system; 130-Ground receiving system; 200-Downhole production instrument; 1-Upper connector; 2-Outer protective casing; 3-Screen pipe; 4-Lower connector; 401-Inlet; 5-Magnetostrictive transducer sub; 501-Counterweight; 502-Induction coil; 503-Super magnetostrictive rod; 504-Stress spring; 505-Induction plate; 6-Flow pipe of this layer; 7-Circuit control sub; 701-Control chip; 702-Internal pressure sensor; 703-External pressure sensor; 704-Temperature sensor; 8-Flow pipe of other layers; 9-Oil nozzle sub; 10-Battery sub; 11-Sliding sleeve connector. Detailed Implementation

[0018] To further illustrate the technical means and effects adopted by this utility model to achieve its intended purpose, the following detailed description of a sound wave wireless transmission-based data acquisition system based on this utility model is provided in conjunction with the accompanying drawings and specific embodiments.

[0019] The foregoing and other technical contents, features, and effects of this utility model will be clearly presented in the following detailed description of the specific embodiments with reference to the accompanying drawings. Through the description of the specific embodiments, a more in-depth and specific understanding can be gained of the technical means and effects adopted by this utility model to achieve the intended purpose. However, the accompanying drawings are only provided for reference and illustration and are not intended to limit the technical solution of this utility model.

[0020] Example 1 To address the issues of low efficiency and insufficient reliability in existing oil well data acquisition methods using either wired or wireless transmission during secondary production operations, this invention provides a secondary production system based on acoustic wireless transmission. Figures 1 to 5 As shown, Figure 1 This is a schematic diagram of the structure of a sound wave wireless transmission-based data acquisition system provided in an embodiment of this utility model; Figure 2 This is a schematic diagram of the structure of the downhole extraction instrument provided in this embodiment of the utility model; Figure 3 This is a schematic diagram of the internal structure of the downhole extraction instrument provided in this embodiment of the utility model; Figure 4 This is a structural cross-sectional view of the downhole extraction instrument provided in this embodiment of the utility model; Figure 5 This is a working block diagram of the acoustic wireless transmission-based data acquisition system provided in this embodiment of the utility model.

[0021] In this embodiment, the acoustic wireless transmission-based segregation system includes: a ground controller 100 and at least one downhole segregation device 200; the ground controller 100 is connected to the tubing through a wellhead device and is used to generate and transmit downlink control command signals and receive and process uplink data signals.

[0022] In an optional implementation, the ground controller 100 includes a ground control module 110, a ground transmitting system 120, and a ground receiving system 130. The ground control module 110 is electrically connected to the ground transmitting system 120 and the ground receiving system 130, respectively. The ground transmitting system 120 is used to generate downlink control command signals through vibration, and the ground receiving system 130 is used to receive and parse uplink data signals.

[0023] This utility model provides a downhole data acquisition device 200 based on acoustic wireless transmission. The downhole data acquisition device 200 has a magnetostrictive transducer section 5 inside, which uses the magnetostrictive effect to vibrate and emit sound waves. The generated vibration sound wave signal is transmitted to the surface through the tubing coupling. The surface receiving system 130 (such as a detector) detects the corresponding signal and performs data analysis to obtain the signal.

[0024] In this embodiment, multiple downhole production instruments 200 are connected in series in the tubing and separated into layers by packers. Specifically, each downhole production instrument 200 includes a structural housing and a magnetostrictive transducer section 5, a circuit control section 7, and a nozzle section 9 disposed within the structural housing. The magnetostrictive transducer section 5 is rigidly connected to the structural housing and is used to receive drive signals from the circuit control section 7. It generates vibrations based on the drive signals to form an upward data signal, which is coupled to the tubing wall and transmitted to the surface. The magnetostrictive transducer section 5 is also used to detect downward control command signals transmitted from the tubing wall. The circuit control section 7 is electrically connected to the magnetostrictive transducer section 5 and the nozzle section 9, respectively, and is used to control the operation of the magnetostrictive transducer section 5 and the nozzle section 9. The nozzle section 9 is used to adjust the flow rate of the produced fluid in the formation according to the command signals from the circuit control section 7.

[0025] In one optional embodiment, the structural housing includes an upper connector 1, an outer protective tube 2, and a lower connector 4 connected in sequence. The lower connector 4 contains a local flow pipe 6 and other flow pipes 8, forming mutually isolated local and other flow production channels. An inlet 401 is provided on the side wall of the lower connector 4, and the inlet 401 communicates with the local flow production channel. Specifically, the local flow pipe 6 and the other flow pipes 8 are arranged parallel to each other within the structural housing. The local flow pipe 6 communicates with the inlet 401 and the nozzle stub 9 to form the local flow production channel, while the other flow pipes 8 form other flow production channels.

[0026] For example, a screen tube 3 is provided on the outside of the lower connector 4, and the liquid inlet 401 is located in the area covered by the screen tube 3.

[0027] In an optional embodiment, the magnetostrictive transducer section 5 includes: a counterweight 501, an induction coil 502, a super magnetostrictive rod 503, a stress spring 504, and an induction plate 505. The induction coil 502 is arranged around the super magnetostrictive rod 503 and is electrically connected to the circuit control section 7. The stress spring 504 is disposed at one end of the super magnetostrictive rod 503 for applying bias stress. The counterweight 501 is disposed at the other end of the super magnetostrictive rod 503 for inertial counterweight. The induction plate 505 is used to detect the downlink control command signal transmitted by the oil pipe wall.

[0028] For example, the magnetostrictive transducer section 5 is rigidly connected to the upper connector 1 via a sliding sleeve connector 11 to ensure that the vibration signal is efficiently coupled to the oil pipe.

[0029] The magnetostrictive transducer section 5 can generate acoustic vibration signals with controllable frequency and amplitude. The principle is that the downhole data acquisition instrument 200 encodes the data to be transmitted into an electrical signal, controlling the current in the induction coil 502, thereby generating a magnetic field change. This causes the supermagnetic stricture rod 503 to elongate or contract in the changing magnetic field, generating acoustic vibration signals with controllable frequency and amplitude. The vibration signal, as an uplink data signal, is transmitted to the surface through the tubing wall, completing the downhole data transmission. Finally, data signals containing production fluid flow rate or nozzle opening are transmitted to the surface through the tubing coupling. The surface receiving system 130 processes and receives the signals, achieving rapid communication. Similarly, the surface transmitting system 120 vibrates to generate downlink control command signals. The magnetostrictive transducer section 5 detects the downlink control command signals transmitted through the tubing wall, and then uses circuit control section 7 to transmit the collected temperature and pressure data. Furthermore, the flow rate of formation production fluid can be adjusted by controlling the opening of the nozzle section 9.

[0030] Understandably, since the surface controller 100 and the magnetostrictive transducer section 5 both have the functions of transmitting and receiving acoustic vibrations, bidirectional communication between the surface equipment and the downhole production instrument 200 is achieved through the tubing. Furthermore, by using a downhole bridge-type flow valve in conjunction with a pump for construction, data testing of each layer of the well can be completed with just one tubing run. This eliminates the need for cable work and enables rapid communication, achieving low cost, high efficiency, and high reliability.

[0031] In an optional embodiment, the circuit control sub 7 includes a control chip 701 and an internal pressure sensor 702, an external pressure sensor 703, and a temperature sensor 704, all electrically connected to the control chip 701. The internal pressure sensor 702 measures tubing pressure data, the external pressure sensor 703 measures formation pressure data, and the temperature sensor 704 measures formation temperature data. Through these sensors, temperature and internal / external pressure data can be measured within a single downhole production instrument 200, and the nozzle sub 9 can be controlled based on this data.

[0032] In an optional embodiment, the nozzle sub-section 9 is used to control the flow area of ​​the produced liquid in the local formation according to the command signal of the circuit control sub-section 7, so as to adjust the flow rate and open or close the produced liquid channel of the local formation. For example, the nozzle sub-section 9 includes a motor, a transmission mechanism, and a piston rod. The output end of the motor is connected to the piston rod through the transmission mechanism. The transmission mechanism includes a lead screw connected to the output end of the motor and a stroke bracket cooperating with the lead screw. The piston rod is disposed on the stroke bracket. The control chip 701 drives the piston rod to move axially by controlling the forward and reverse rotation of the motor, thereby changing the position of the piston rod in the produced liquid channel of the local formation, thereby adjusting the flow rate and opening or closing the produced liquid channel of the local formation.

[0033] Furthermore, the oil nozzle section 9 also includes a limit switch, which is electrically connected to the control chip 701 and is used to detect the extreme position of the piston rod. When the piston rod touches the limit switch, the motor power is automatically cut off.

[0034] In an optional implementation, each downhole extraction device 200 also includes a battery subsection 10 for supplying power to the magnetostrictive transducer subsection 5, the circuit control subsection 7, and the nozzle subsection 9, respectively.

[0035] To enable those skilled in the art to fully understand and implement this utility model, the following supplementary explanation of the specific implementation principle of this utility model is provided in conjunction with a specific application scenario.

[0036] The present invention relates to a sound wave wireless transmission-based segregation system, which mainly comprises two major systems: a downhole system and a surface system. The downhole system mainly consists of a downhole segregation instrument 200, a packer, tubing couplings, and plugs; the surface system mainly consists of a surface controller 100, surface pipelines, and a host computer.

[0037] The downhole production analyzer 200 connects to the production tubing string and is inserted into the well along with the production pump. The downhole production analyzer 200 is separated by a packer, and a bridge valve is installed below the pump to provide a fluid passage, facilitating later packer setting. The control chip 701 stores a control program that generates preset vibration pulse signals, including nozzle switching actions and temperature and pressure data acquisition. These vibration pulse signals are then transmitted to the surface equipment via the magnetostrictive transducer section 5 through the tubing coupling. The surface receiving system 130 processes the data signals and then collects and controls them via host computer software, thus achieving wireless transmission.

[0038] The downhole production instrument 200 includes an upper connector 1, an outer protective tube 2, a screen tube 3, a lower connector 4, a magnetostrictive transducer sub 5, a local flow tube 6, a circuit control sub 7, other flow tubes 8, a nozzle sub 9, a battery sub 10, and a sliding joint 11. The magnetostrictive transducer sub 5 and the battery sub 10 are both mounted on the sliding joint 11. One end of the local flow tube 6 and the other flow tube 8 are mounted on the sliding joint 11, and the other end is mounted on the lower connector 4. The nozzle sub 9 and the circuit control sub 7 are both mounted on the lower connector 4. The screen tube 3 is mounted on the lower connector 4. One end of the outer protective tube 2 is threaded to the lower connector 4, and the other end is threaded to the upper connector 1. Formation production fluid flows in through the inlet 401 and is controlled by the nozzle sub 9. The circuit control sub 7 controls a motor via a control chip 701 to control the nozzle opening.

[0039] The downhole production analyzer 200 has two flow channels: a flow channel and a measurement channel. The flow channel is for producing fluid from other layers. Produced fluid flows from the lower connector 4 through the current layer's flow pipe 6 into the upper connector 1. The pressure inside the pipe can be measured by the internal pressure sensor 702, and then it flows out from the upper connector 1, thus flowing into the next layer's channel. The measurement channel is for producing fluid from the current layer. Produced fluid flows in from the screen pipe 3 and through the nozzle stub 9 into the current layer's channel.

[0040] Data communication between the downhole production analyzer 200 and the surface controller 100 is achieved through tubing and surface pipelines. Specifically, the downhole production analyzer 200 contains a magnetostrictive transducer section 5, which generates vibration waves based on the principle of magnetostrictive vibration. These waves are then coupled to the tubing coupling and transmitted to the surface. The surface controller 100 contains a high-sensitivity detector that detects vibration signals in the wellhead tubing. After amplification and filtering of the signals by internal circuitry, the signals are analyzed into actual pressure, temperature, and nozzle opening values, which are then displayed on the host computer software interface, realizing data transmission of the production analyzer system. Simultaneously, vibration waves generated by the surface transmission system 120 are coupled to the surface wellhead pipeline and transmitted through the tubing to the downhole production analyzer 200. After receiving and analyzing the signals, the surface controller 100 identifies the surface control signals and provides feedback, achieving bidirectional communication and control between the surface controller 100 and the downhole production analyzer 200.

[0041] This invention relates to a sound wave wireless transmission-based wellbore system. It utilizes the tubing wall as a solid-state sound wave transmission channel and employs a structure where a magnetostrictive transducer section is rigidly connected to the tubing. This allows the sound wave signal to propagate along the metal tubing wall with low attenuation and high speed, achieving stable and reliable two-way wireless communication between the surface and wells thousands of meters underground. This system not only successfully eliminates reliance on cables, simplifying the tubing structure and operational procedures and significantly reducing construction costs and risks, but also solves the problems of rapid signal attenuation and insufficient transmission distance in traditional wireless technologies. Thus, it achieves rapid communication while significantly reducing transmission costs.

[0042] It should be noted that, in this document, relational terms such as "first" and "second" are used merely to distinguish one entity or operation from another, and do not necessarily require or imply any such actual relationship or order between these entities or operations. Furthermore, the terms "comprising," "including," or any other variations are intended to cover non-exclusive inclusion, such that an article or device comprising a list of elements includes not only those elements but also other elements not expressly listed. Without further limitations, an element defined by the phrase "comprising one..." does not exclude the presence of other identical elements in the article or device comprising said element. Terms such as "connected" or "linked" are not limited to physical or mechanical connections but can include electrical connections, whether direct or indirect. The orientations or positional relationships indicated by terms such as "upper," "lower," "left," and "right" are based on the orientations or positional relationships shown in the accompanying drawings and are used only for the convenience of describing the invention and simplifying the description, and do not indicate or imply that the device or element referred to must have a specific orientation, be constructed and operated in a specific orientation, and therefore should not be construed as a limitation of the invention.

[0043] The above description, in conjunction with specific preferred embodiments, provides a further detailed explanation of the present invention. It should not be construed that the specific implementation of the present invention is limited to these descriptions. For those skilled in the art, various simple deductions or substitutions can be made without departing from the concept of the present invention, and all such modifications and substitutions should be considered within the protection scope of the present invention.

Claims

1. A data acquisition system based on acoustic wireless transmission, characterized in that, include: Surface controller and at least one downhole production instrument; The ground controller is connected to the tubing via a wellhead device and is used to generate and transmit downlink control command signals, and to receive and process uplink data signals. Multiple downhole production instruments are connected in series in the tubing and are sealed between layers by packers; each downhole production instrument includes a structural housing and a magnetostrictive transducer section, a circuit control section and a nozzle section disposed within the structural housing; The magnetostrictive transducer section is rigidly connected to the structural housing and is used to receive the drive signal from the circuit control section and generate vibration according to the drive signal to form the uplink data signal, which is coupled to the tubing wall for transmission to the ground. The magnetostrictive transducer section is also used to detect the downlink control command signal transmitted by the tubing wall. The circuit control section is electrically connected to the magnetostrictive transducer section and the nozzle section respectively and is used to control the operation of the magnetostrictive transducer section and the nozzle section respectively. The nozzle section is used to adjust the flow rate of the produced fluid in the formation according to the command signal from the circuit control section.

2. The acoustic wave wireless transmission-based data acquisition system according to claim 1, characterized in that, The structural shell includes an upper connector, an outer protective tube, and a lower connector connected in sequence. Inside, there are flow pipes for this layer and flow pipes for other layers, forming mutually isolated liquid production channels for this layer and liquid production channels for other layers. An inlet is provided on the side wall of the lower connector, and the inlet is connected to the liquid production channel for this layer.

3. The acoustic wireless transmission-based data acquisition system according to claim 2, characterized in that, The flow tubes in this layer and the flow tubes in other layers are arranged in parallel within the structural housing. The flow tubes in this layer are connected to the liquid inlet and the oil nozzle section to form the liquid production channel in this layer, and the flow tubes in other layers form the liquid production channel in other layers.

4. The acoustic wave wireless transmission-based data acquisition system according to claim 2, characterized in that, The magnetostrictive transducer section includes: a counterweight, an induction coil, a super magnetostrictive rod, a stress spring, and a sensing plate. The induction coil is arranged around the super magnetostrictive rod and is electrically connected to the circuit control section. The stress spring is located at one end of the super magnetostrictive rod and is used to apply bias stress. The counterweight is located at the other end of the super magnetostrictive rod and is used for inertial counterweight. The sensing plate is used to detect the downlink control command signal transmitted by the oil pipe wall.

5. The acoustic wireless transmission-based data acquisition system according to claim 4, characterized in that, The magnetostrictive transducer section is rigidly connected to the upper connector via a sliding sleeve joint.

6. The acoustic wave wireless transmission-based data acquisition system according to claim 2, characterized in that, The circuit control section includes a control chip, and an internal pressure sensor, an external pressure sensor, and a temperature sensor, which are electrically connected to the control chip respectively; wherein, the internal pressure sensor is used to measure the pressure data inside the tubing, the external pressure sensor is used to measure the formation pressure data, and the temperature sensor is used to measure the formation temperature data.

7. The acoustic wave wireless transmission-based data acquisition system according to claim 6, characterized in that, The nozzle short section is used to control the flow area of ​​the produced liquid in the local formation according to the instruction signal of the circuit control short section, so as to adjust the flow rate and open or close the produced liquid channel in this formation. The oil nozzle section includes a motor, a transmission mechanism, and a piston rod. The output end of the motor is connected to the piston rod through the transmission mechanism. The transmission mechanism includes a lead screw connected to the output end of the motor and a stroke bracket that cooperates with the lead screw. The piston rod is mounted on the stroke bracket. The control chip controls the forward and reverse rotation of the motor to drive the piston rod to move axially, thereby changing the position of the piston rod in the liquid production channel of this layer, thus adjusting the flow rate and opening or closing the liquid production channel of this layer.

8. The acoustic wireless transmission-based data acquisition system according to claim 7, characterized in that, The nozzle section also includes a limit switch, which is electrically connected to the control chip and is used to detect the extreme position of the piston rod.

9. The acoustic wireless transmission-based data acquisition system according to claim 1, characterized in that, Each of the downhole production instruments also includes a battery subsection for supplying power to the magnetostrictive transducer subsection, the circuit control subsection, and the nozzle subsection, respectively.

10. The acoustic wireless transmission-based data acquisition system according to claim 1, characterized in that, The ground controller includes a ground control module, a ground transmitting system, and a ground receiving system. The ground control module is electrically connected to the ground transmitting system and the ground receiving system, respectively. The ground transmitting system is used to generate the downlink control command signal through vibration, and the ground receiving system is used to receive and parse the uplink data signal.

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