Inclination measurement while drilling device and method for multi-band pulse communication

Abstract

The invention relates to a multi-band pulse communication while-drilling inclinometry device and method, and relates to the technical field of while-drilling inclinometry equipment. A fishing head is connected with a shell pipe barrel through a centralizer, and a while-drilling detection module for monitoring the drilling condition is arranged in the shell pipe barrel; the shell pipe barrel is further connected with a pulse generation module through a centralizer and a flexible hinge joint which are connected in series, and a valve head assembly of the pulse generation module forms pulse liquid flow with variable strength in the mode that a flow guide channel which is adjustable in flow channel section and intermittently opened and closed is constructed in the valve shell barrel. The valve head assembly is further matched with the valve shell barrel to construct a bypass flow guide auxiliary cavity structure which supplies reinforcing liquid flow in a manner of being associated with the real-time conduction state of the flow guide channel. According to the invention, the pulse signals of multiple frequency bands can be adjustably generated, so that the pulse communication efficiency is improved, the data transmission period is shortened, the reinforcing liquid flow is supplied in a linkage manner to improve the intensity of the pulse liquid flow, and the noise immunity and the transmission quality of the pulse signals are improved.

Description

Technical Field

[0001] The present invention relates to the technical field of measurement-while-drilling equipment, and particularly to a measurement-while-drilling device and method for multi-band pulse communication. Background Art

[0002] During the exploration and development of oil and gas fields, it is necessary to measure the drilling trajectory to confirm whether it deviates from the target oil reservoir position and the drilling route. The early traditional measurement method was that operators lowered the detection equipment along the drilling channel into the well through a cable or optical fiber to periodically measure the bottom-hole drilling trajectory. However, this measurement method could not effectively send the detection equipment to the bottom of the well in an inclined well, and effective measurement could not be achieved. In addition, the wellbore was prone to collapse or blockage due to geological conditions and other problems, which would also affect the logging work. On the other hand, during the drilling process, drilling fluid needed to be continuously added for circulation. The drilling fluid carried the cuttings damaged by downhole drilling from the bottom of the well to the ground. During the circulation process, the drilling fluid would gradually invade the rock wall. Therefore, when detecting after the drilling was completed, the drilling fluid would interfere with various parameters of the formation to a certain extent. In order to improve the detection quality and accuracy, measurement-while-drilling technology was gradually developed, replacing the traditional measurement method, enabling the detection equipment to descend synchronously with the drill string underground, collecting information such as the drilling inclination and drilling trajectory, and then using the measured drilling parameters and formation parameters to timely adjust the drill bit trajectory to ensure the drilling accuracy.

[0003] Currently, measurement-while-drilling tools MWD and logging-while-drilling tools LWD are becoming more and more widely used. Whether it is the drilling engineering parameters measured by measurement-while-drilling MWD and logging-while-drilling LWD, such as well inclination data, geological parameters, formation gamma count, resistivity value, and acoustic wave data, or other parameters measured by rotary geosteering tools, they all need to be transmitted to the surface system through a pulse signal generator by mud. The surface system collects the waveform output by the pulse signal generator through a pressure sensor on the drilling riser and decodes it to restore the downhole engineering parameters and geological parameters in real time. However, the pulse signal generators of existing measurement-while-drilling detection tools usually achieve the formation of pulsed fluid flow based on the principle of a small valve driving a large valve of a solenoid valve. Although the pulse signal corresponding to the pulsed fluid flow can be used for data transmission, it has defects such as a long action stroke time, a low data transmission baud rate, and poor practicability. In particular, with the increase in drilling depth and the complexity of the downhole environment, the high power consumption and low pulling force of the solenoid valve can no longer meet the usage requirements and cannot be effectively applied to harsh working conditions. Under such conditions, since the rotary valve pulsator can be used in a high-temperature environment, the low-power motor improves the battery service life and anti-electromagnetic interference. The driving force and service life of the motor are much greater than those of the electromagnetic coil, and the use of the rotary valve eliminates the oil filling link of the pulsator, shortening the production and maintenance time, so it is widely used.

[0004] For example, the existing patent with publication number CN111075437B discloses a QDT type rotary valve pulser, which has a drilling fluid channel at one end of the valve seat tube, one end of the valve stem is arranged corresponding to the drilling fluid channel, the rotary valve head is used to block the two drilling fluid channels opened at one end of the valve seat tube, the filter cartridge is sleeved on the valve stem, one end of the drive component is connected to the other end of the valve stem, the other end of the drive component is connected to a cable, the drive component drives the valve stem to rotate, which is used to control the opening and closing of the drilling fluid channel, the cable is used to transmit electrical energy to the drive component, one end of the connector component is connected to the other end of the cable connected to the other end of the drive component, the connector component is used to transmit power signals between downhole instruments, and the on and off time and interval of the drive component inside the pulser are controlled by the control signal, the rotation of the rotary valve is controlled, thereby controlling the width and interval of the pulse, and realizing the generation of the signal. However, existing rotary valve pulsers only have one flow channel size, and their intermittent on-off operation can only represent pulse signals of a single frequency band, making it impossible to quickly and concisely represent multiple different drilling engineering parameters. As a result, during actual communication, existing pulse signal generators can only use long-segment pulse waveforms formed by a single continuous pulse flow fluctuation over a long period of time to represent detection data, which reduces the efficiency and timeliness of pulse communication, affects the timeliness of ground system data acquisition, and has communication lags, making it impossible to adjust the drill bit in a timely manner according to drilling conditions. In addition, existing pulse signal generators usually use a single valve body structure to adjust the flow flow conditions. The resulting pulse flow fluctuation peak is limited, and the pulse signal strength is insufficient. During the pulse communication process, due to noise interference and energy attenuation over long distances, the pulse signal with limited strength is easily distorted and attenuated in the continuously changing and gradually increasing depth drilling environment. It is impossible to accurately generate multiple discrete pulse flow fluctuations at different pressure levels, resulting in the ground system being unable to reliably identify and guaranteeing the accuracy and effectiveness of pulse communication. Summary of the invention

[0005] The present invention aims to provide a multi-band pulse communication while drilling inclination measurement device and method that can form pulse signals of multiple frequency bands by intermittently outputting pulse liquid flows of different flow rates, and can also enhance the strength of the pulse signal by supplying a reinforcing liquid flow in conjunction with the real-time flow rate of the diversion channel, so as to solve the problem that the pulser signal generator provided in the existing while drilling inclination measurement equipment can usually only generate a single pulse liquid flow fluctuation with limited pulse signal intensity, and it uses the binary principle for coding communication, resulting in low transmission efficiency and long data transmission cycle. In addition, the pulse liquid flow fluctuation generated by it is extremely susceptible to noise interference in the drilling well and energy attenuation during long-distance transportation underground. The pulse liquid flow fluctuation with weaker intensity cannot be effectively collected, and the capture of the pulse signal is difficult and there is a problem of signal distortion.

[0006] The technical solution adopted by the present invention is as follows: a measurement-while-drilling (MWD) device for multi-band pulse communication, including a housing tube connected to a fishing head through a centralizer. Inside the housing tube, there is an MWD module capable of monitoring real-time parameters of drilling. One end of the housing tube away from the fishing head is connected to a pulse generation module through a series of centralizers and a flexible hinge joint, which can output pulse signals according to the real-time detection data obtained by the MWD module. The valve head assembly of the pulse generation module forms a pulsed liquid flow with variable intensity in such a way that it can construct a diversion channel with an adjustable flow passage cross-section and intermittent opening and closing inside the valve housing tube. Moreover, the valve head assembly can also cooperate with the valve housing tube to construct a bypass diversion secondary cavity structure for supplying a reinforcing liquid flow associated with the real-time conduction state of the diversion channel. Its advantages are as follows: The pulse generation module provided in this application uses the cooperation between the valve head assembly and the valve housing tube to adjustably construct multiple conduction channels with different minimum flow cross-sections. When different conduction channels are independently penetrated, liquid flow fluctuations with different instantaneous hydraulic pressure increments and different peaks can be generated in the conduction channels, making the intensity of the formed pulsed liquid flow different, and the frequency bands of the corresponding pulse signals can also be differently defined, realizing the controllable formation of multi-band pulse signals, facilitating the efficient characterization of well inclination data quickly and accurately, improving the quality and accuracy of data transmission, enhancing the effect of data feedback and the efficiency of data transmission, and shortening the data transmission cycle. The bypass diversion secondary cavity structure provided in this application can supply a reinforcing liquid flow associated with the instantaneous flow rate of the pulsed liquid flow, enhancing the peak value of the liquid flow fluctuation and the overall intensity of the pulsed liquid flow, improving the anti-noise interference ability of the pulsed liquid flow during transportation in the well and reducing the influence caused by energy attenuation during transportation, ensuring that the finally output pulsed liquid flow still has a strong fluctuation peak value, enabling it to be effectively collected, reducing the difficulty of capturing pulse signals, enhancing the accuracy and integrity of its characterized data, and reducing the risk of pulse signal distortion and loss.

[0007] According to a preferred embodiment, the valve housing tube is connected to the mounting sleeve through a sealing connection assembly, and a valve head assembly capable of relative position change is inserted into the valve housing tube. The valve head assembly is connected to a drive unit installed in the mounting sleeve through a transmission assembly that movably passes through the sealing connection assembly, and a control unit for setting the motion parameters of the drive unit is also provided in the mounting sleeve. Its advantages are as follows: The pulse generation module provided in this application can double improve the efficiency and quality of communication from the directions of increasing the communication frequency band and enhancing the pulse intensity, ensuring the effectiveness and accuracy of pulse communication.

[0008] According to a preferred embodiment, the first valve sleeve and the second valve sleeve of the valve head assembly are inserted into the valve housing tube at intervals, and the first valve core and the second valve core are movably inserted into the valve body cavity of the first valve sleeve and the second valve sleeve respectively; an elastic diaphragm is further provided between the first valve sleeve and the second valve sleeve to form an annular body cavity in cooperation with the valve housing tube, and an annular reinforcement push block capable of axial movement is further provided in the annular body cavity; the annular reinforcement push block is connected to the second valve core via an L-shaped linkage rod passing through the second valve sleeve. The advantage is that the first valve core provided in the present application can be controlled to rotate, thereby intermittently forming different diversion channels, and the instantaneous hydraulic fluctuation of the liquid flow in the diversion channel is used to pressurize and push the second valve core to move, realizing the opening and closing linkage of the bypass diversion sub-cavity structure and the diversion channel, thereby improving the intensity and peak value of the pulsed liquid flow, so that the final output pulsed liquid flow has stronger fluctuation characteristics and fluctuation peak value, effectively resisting noise interference and transmission energy attenuation loss, and improving communication quality.

[0009] According to a preferred embodiment, the sidewall surface of the first valve core body of the first valve core is provided with a first transverse through hole, a second transverse through hole, and a third transverse through hole spaced circumferentially therebetween; and the end surface of the first valve core body facing the second valve core is provided with a first central vertical through hole that can simultaneously communicate with the first transverse through hole, the second transverse through hole, and the third transverse through hole. The advantage of this is that by providing first, second, and third transverse through holes with different cavity cross sections, the present application achieves the distinct definition of different diversion channels, thereby forming pulsed liquid flows of different intensities, thereby achieving the generation and characterization of multi-band pulse signals.

[0010] According to a preferred embodiment, a second central vertical through hole is provided on the end face of the second valve core body of the second valve core facing the first valve core body, and a plurality of fourth transverse through holes connected to the second central vertical through hole are provided on the side face of the second valve core body in a rotationally symmetrical manner.

[0011] According to a preferred embodiment, a first elastic member is sleeved on the outer side of the second valve core body to define its initial insertion position in the second valve sleeve.

[0012] According to a preferred embodiment, the two ends of the sealing connection cylinder of the sealing connection assembly are respectively connected to the valve housing cylinder and the mounting sleeve, and a rotating sleeve is inserted in the sealing connection cylinder, and a limit bearing is sleeved on the rotating sleeve to limit the relative rotatable connection between it and the sealing connection cylinder.

[0013] According to a preferred embodiment, the lower axial end of the transmission shaft of the transmission assembly is connected to the first valve core body. The transmission shaft is arranged in the rotating shaft sleeve, and a speed reducer is connected to the upper axial end of the transmission shaft. The speed reducer is in transmission connection with a coupling away from the upper axial end of the transmission shaft.

[0014] The present invention also provides a measurement-while-drilling (MWD) method for multi-band pulse communication, including the MWD device for multi-band pulse communication in the foregoing content, and further including the following steps: The MWD module can collect the well inclination data of the drilling section, and the data collected by it is transmitted to the control unit through a cable. The control unit generates a control instruction according to the detection data, so as to control the driving unit to rotate with a change in motion parameters according to the instruction. The rotational motion of the driving unit is transmitted to the first valve core of the valve head assembly through the transmission assembly, so that the valve head assembly and the valve housing cooperate to construct a diversion channel with an adjustable flow channel cross-section and intermittent opening and closing, thereby forming a pulsed liquid flow with variable intensity. And the valve head assembly can also cooperate with the valve housing to construct a bypass diversion sub-chamber structure for supplying a reinforcing liquid flow associated with the real-time conduction state of the diversion channel.

[0015] According to a preferred embodiment, the MWD module collects the well inclination data in real time through a MWD instrument and a gyro detection unit, and the control unit can compare and verify the well inclination data collected by the MWD instrument and the gyro detection unit, so as to correct the data deviation.

[0016] The beneficial effects of the present invention are as follows: The pulse generation module provided in the present application uses the cooperation between the valve head assembly and the valve housing to adjustably construct a variety of conduction channels with different minimum flow cross-sections. When different conduction channels are separately penetrated, liquid flow fluctuations with different instantaneous hydraulic pressure increments and different peaks can be generated in the conduction channels, so that the intensity of the formed pulsed liquid flow is different, and the frequency bands of the corresponding pulse signals can also be defined differently, realizing the controllable formation of multi-band pulse signals, facilitating the efficient characterization of well inclination data quickly and accurately, improving the quality and accuracy of data transmission, enhancing the effect of data feedback and the efficiency of data transmission, shortening the data transmission cycle, improving the timeliness of data during pulse communication, and facilitating the timely and accurate adjustment of the drilling process.

[0017] The bypass diversion sub-cavity structure set up in the present application can supply reinforcing fluid flow in association with the instantaneous flow rate of the pulse fluid flow, thereby increasing the fluid flow fluctuation peak and the overall strength of the pulse fluid flow, improving the noise interference resistance of the pulse fluid flow during transportation in the drilling well and reducing the impact of energy attenuation during transportation, effectively defining and maintaining multiple discrete and reliable pulse fluid pressure levels, facilitating high-quality transmission of pulse signals of different frequency bands for pulse fluid flows of different intensities, enabling the ground system to effectively identify and ensure that the final output pulse fluid flow still has a strong fluctuation peak, so that it can be effectively collected, reducing the difficulty of capturing the pulse signal, improving the accuracy and integrity of its characterization data, and reducing the risk of pulse signal distortion and loss. BRIEF DESCRIPTION OF THE DRAWINGS

[0018] Figure 1 This is a schematic structural diagram of a preferred multi-band pulse communication while drilling inclination measurement device proposed by the present invention; Figure 2 It is a schematic plan view of a preferred multi-band pulse communication while drilling inclination measurement device proposed by the present invention; Figure 3 This is a partial axial cross-sectional view of a preferred multi-band pulse communication while drilling inclination measurement device proposed by the present invention; Figure 4 The present invention proposes an optimal multi-band pulse communication while drilling inclination measurement device. Figure 3 Schematic diagram of the transverse section at point A; Figure 5 The present invention proposes an optimal multi-band pulse communication while drilling inclination measurement device. Figure 3 Schematic diagram of the transverse section at point B; Figure 6 This is a schematic diagram of the expansion of the annular wall of the first valve core body of a preferred multi-band pulse communication while drilling inclination measurement device proposed by the present invention; Figure 7 This is a schematic structural diagram of a preferred multi-band pulse communication while drilling inclination measurement device proposed in the present invention when the first transverse through hole is connected.

[0019] Reference numerals list 1: Fishing head; 2: Centralizer; 3: Outer shell tube; 4: Measurement-while-drilling module; 5: Flexible hinge joint; 6: Pulse generation module; 41: Inclination measuring instrument while drilling; 42: Gyroscopic detection unit; 43: Energy supply unit; 61: Valve housing tube; 62: Valve head assembly; 63: Sealing connection assembly; 64: Mounting sleeve; 65: Transmission assembly; 66: Driving unit; 67: Control unit; 611: First through port; 612: Second through port; 613: Filter plate; 621: First valve sleeve; 622: Second valve sleeve; 623: First valve core; 624: Second valve core; 625: Elastic diaphragm; 626: Annular reinforcement push block; 627: L-shaped linkage rod; 628: First elastic member; 6211: Diversion through port; 6212: Accommodating step; 6221: Narrow edge step; 6222: First through shaft hole; 6223: Second through shaft hole; 6231: First valve core body; 6232: First transverse through hole; 6233: Second transverse through hole; 6234: Third transverse through hole; 6235: First central vertical through hole; 6241: Second valve core body; 6242: Second central vertical through hole; 6243: Fourth transverse through hole; 631: Sealing connection cylinder; 632: Rotating shaft sleeve; 633: Limiting bearing; 651: Transmission shaft rod; 652: Reducer; 653: Coupling. Detailed implementation mode

[0020] The following is a detailed description with reference to the accompanying drawings.

[0021] This application provides a measurement-while-drilling inclination device for multi-band pulse communication, which includes a fishing head 1, a centralizer 2, an outer shell tube 3, a measurement-while-drilling module 4, a flexible hinge joint 5 and a pulse generation module 6.

[0022] According to Figure 1 and Figure 2In a specific embodiment shown, the fishing head 1 is connected to the outer casing tube 3 through a centralizer 2. A measurement-while-drilling (MWD) module 4 capable of monitoring real-time parameters such as the well inclination data of the drilled section of the well is provided inside the outer casing tube 3. One end of the outer casing tube 3 away from the fishing head 1 is connected to a pulse generation module 6 through a series-connected centralizer 2 and a flexible hinge joint 5. The pulse generation module 6 can generate control instructions based on the real-time detection data collected by the MWD module 4 and output variable multi-stage pulse signals according to the control instructions. The valve head assembly 62 of the pulse generation module 6 forms a pulsed liquid flow with controllable variable intensity in such a way that it can construct a diversion channel with an adjustable flow channel cross-section and intermittent opening and closing within the valve housing cylinder 61, thereby controllably outputting multi-stage pulse signals. Moreover, the valve head assembly 62 can also cooperate with the valve housing cylinder 61 to construct a bypass diversion sub-chamber structure for supplying a reinforcing liquid flow associated with the real-time conduction state of the diversion channel. The valve head assembly 62 provided in this application can form multiple conduction channels with different minimum flow cross-sections according to requirements. When different conduction channels are opened, liquid flow fluctuations with different instantaneous hydraulic pressure increments and different peaks can be generated within the conduction channels, resulting in differences in the intensity of the formed pulsed liquid flow. The frequency bands of the corresponding pulse signals can also be defined differently, realizing the controllable formation of multi-band pulse signals, facilitating the efficient characterization of well inclination data quickly and accurately, improving the quality and accuracy of data transmission, enhancing the effect of data feedback, improving the timeliness of data during pulse communication, and facilitating the timely and accurate adjustment of the drilling process. The bypass diversion sub-chamber structure provided in this application can supply a reinforcing liquid flow associated with the instantaneous flow rate of the pulsed liquid flow, enhancing the peak value of the liquid flow fluctuation and the overall intensity of the pulsed liquid flow, improving the stability and noise immunity of the pulse signal, enhancing the accuracy and integrity of the data it represents, reducing the risk of pulse signal distortion and loss, reducing the impact caused by energy attenuation during the transmission process, effectively defining and maintaining the pressure levels of multiple discrete and reliable pulsed liquid flows, and facilitating the high-quality transmission of different-frequency-band pulse signals by pulsed liquid flows with different intensities, enabling the ground system to effectively identify them.

[0023] Preferably, the fishing head 1 is connected to the centralizer 2 in a detachable manner such as a sleeve / insertion method, enabling the fishing head 1 to be conveniently assembled with the main body of the measurement-while-drilling string, ensuring the convenience of disassembly and assembly and the connection stability. The fishing head 1 is located at the upper axial end of the measurement-while-drilling device, making it convenient to be fished and connected by external equipment. Specifically, the fishing head 1 can directly refer to the relevant components in the existing patent with the publication number CN114658419A. Preferably, the centralizer 2 adopts a sealed connection sleeve structure and rollers that are arranged on the side surface of the connection sleeve torus and can rotate. Specifically, several rollers are arranged at circumferential intervals, facilitating wire threading inside the connection sleeve structure. Preferably, both ends of the outer shell tube 3 are docked with the centralizer 2, making the inner cavity of the tube string penetrate, facilitating the cable connection between the measurement-while-drilling module 4 and the pulse generation module 6, and facilitating the energy and information transmission between the two. Specifically, the inner part of the outer shell tube 3 has limiting structural bodies such as internal threads and fixed ring stops, thus facilitating the fixed installation of the measurement-while-drilling module 4, enabling the measurement-while-drilling module 4 to be detachably installed in the outer shell tube 3, avoiding relative movement between the measurement-while-drilling module 4 and the outer shell tube 3, and enhancing the placement stability and structural connection strength. Preferably, a sealing plate is arranged in the upper inner cavity of the outer shell tube 3 to separate its inner cavity, preventing abnormal intrusion of liquid at the end of the outer shell tube 3 close to the fishing head 1 and avoiding the risk of damaging the measurement-while-drilling module 4. Preferably, a sealing gasket is arranged at the docking port between the centralizer 2 and the flexible hinge joint 5 to ensure the sealing of the formed inner cavity space, prevent external liquid from invading the accommodation space, and ensure the isolation and safety of the measurement-while-drilling module 4 and the pulse generation module 6.

[0024] Preferably, the real-time parameters of drilling refer to the wellbore inclination of the latest formed drilling section during the drilling process of the drill string and well inclination data such as the drilling path.

[0025] Such as Figure 2As shown in the figure, the measurement-while-drilling (MWD) module 4 includes an inclinometer 41, a gyroscopic detection unit 42, and a power supply unit 43. Specifically, the inclinometer 41, the gyroscopic detection unit 42, and the power supply unit 43 are fixed to the inner wall of the outer casing tube 3 by means such as snap connection and bolt connection. Preferably, the inclinometer 41 is composed of a probe tube and a gamma integrated core structure. The gamma integrated core structure is installed inside the probe tube, and the probe tube is arranged inside the outer casing tube 3 by means of limit clamping. Among them, the gamma probe counting range is: 250 CPS; the sensitivity is 1.5 CPS / API, the accuracy is 5%, the resolution is 200 mm, the maximum temperature resistance is 150 °C, the maximum pressure resistance is 140 MPa, the maximum allowable impact is 1000 G / 0.5 ms, and the maximum allowable vibration is 30 G / 50 - 300 Hz. Preferably, the gyroscopic detection unit 42 is composed of a probe tube, a circuit structure, and sensors. The circuit structure and the sensors are both arranged inside the probe tube. The circuit structure mainly includes an acquisition and solution circuit, a control and transmission circuit, etc. connected to the sensors. Preferably, the control and transmission circuit of the gyroscopic detection unit 42 is communicatively connected to the inclinometer 41, so as to work simultaneously or independently according to requirements. Preferably, the power supply unit 43 is connected to the inclinometer 41 and the gyroscopic detection unit 42 through a cable, so that the power supply unit 43 can controllably supply power to the inclinometer 41 and / or the gyroscopic detection unit 42. Specifically, the data collected by the inclinometer 41 and the gyroscopic detection unit 42 can be compared and verified with each other, so as to improve the accuracy of the well inclination parameters output by feedback through mutual compensation and correction of the data collected by the two. Preferably, the gyroscopic detection unit 42 includes a gyro sensor and a connector. The gyro sensor is installed on the circuit bracket for collecting data; the connector is installed on the circuit bracket for connecting the power supply unit 43 and the control unit 67. The gyro sensor can collect drilling trajectory parameters within a measurement range of the inclination angle of 0 ± 90°. In this application, the sensor is changed from the traditional single-axis to the three-axis of the microelectromechanical gyro sensor. By calculating and analyzing the data collected by the three-axis sensor, the inclination angle, the positioning angle, etc. are obtained, and it is realized to work within a measurement range of the inclination angle of 0 ± 90°. Since the distance between the wellbore drilled during drilling and the adjacent well is small or operations need to be carried out in the casing, the casing will generate magnetic interference. When performing measurement-while-drilling in these environments with magnetic interference, the wireless measurement-while-drilling instrument represented by the inclinometer 41 based on magnetic measurement cannot be used normally. At this time, this application uses the gyroscopic detection unit 42 to be able to accurately measure the well inclination parameters in an environment with magnetic field interference, thereby improving the measurement accuracy and data quality and ensuring the correctness of the operation adjustment made by the ground feedback.

[0026] As Figure 2 , Figure 3 and Figure 7As shown, the pulse generation module 6 includes a valve housing cylinder 61, a valve head assembly 62, a sealed connection assembly 63, a mounting sleeve 64, a transmission assembly 65, a drive unit 66, and a control unit 67. Preferably, the valve housing cylinder 61 is connected to the mounting sleeve 64 through the sealed connection assembly 63. Preferably, a valve head assembly 62 capable of forming a pulsed liquid flow in a manner of relative position change is inserted into the valve housing cylinder 61. Preferably, the valve head assembly 62 is connected to the drive unit 66 installed in the mounting sleeve 64 through the transmission assembly 65 that movably passes through the sealed connection assembly 63. Further preferably, a control unit 67 for adjustably defining the motion parameters of the drive unit 66 is further provided in the mounting sleeve 64.

[0027] Preferably, a first through hole 611 and a second through hole 612 for communicating the inside and outside of the cylinder cavity are formed in the side wall of the cylinder body of the valve housing cylinder 61. Preferably, a plurality of first through holes 611 are formed in the barrel wall section where the first valve sleeve 621 is inserted at circumferential intervals. Further preferably, a plurality of diversion through holes 6211 corresponding to the first through holes 611 one by one are formed in the side wall of the first valve sleeve 621. Specifically, the first through hole 611 and the diversion through hole 6211 may be through channels with a rectangular cross-section. Preferably, a plurality of second through holes 612 are circumferentially spaced apart in a manner capable of communicating with the annular cavity. Specifically, the second through hole 612 may be a through channel with a circular cross-section convenient for the installation of a check valve. Preferably, filter plates 613 capable of performing coarse particle filtration on the drilling fluid flow formed by the drilling mud are embedded in both the first through hole 611 and the second through hole 612. Preferably, a check valve capable of defining the unidirectional inflow of the drilling fluid into the annular cavity is further provided in the second through hole 612.

[0028] Preferably, the valve head assembly 62 includes a first valve sleeve 621, a second valve sleeve 622, a first valve core 623, a second valve core 624, an elastic diaphragm 625, an annular reinforcing push block 626, an L-shaped linkage rod 627, and a first elastic member 628. Preferably, the surfaces of the first valve sleeve 621 and the second valve sleeve 622 are sprayed with cemented carbide to increase wear resistance. Preferably, the first valve core 623 and the second valve core 624 are made of cemented carbide material, making them wear-resistant and erosion-resistant. Preferably, the first valve sleeve 621 and the second valve sleeve 622 of the valve head assembly 62 are inserted into the valve housing cylinder 61 at intervals, and the first valve core 623 and the second valve core 624 are respectively movably inserted into the valve body cavities of the first valve sleeve 621 and the second valve sleeve 622. Preferably, an elastic diaphragm 625 capable of cooperating with the valve housing cylinder 61 to form an annular partition cavity is further provided between the first valve sleeve 621 and the second valve sleeve 622. Preferably, an annular reinforcing push block 626 capable of axial movement is further provided in the annular partition cavity. Specifically, both ends of the elastic diaphragm 625 made of wear-resistant rubber or wear-resistant silicone sheet and having a frustum-shaped ring wall are respectively connected to the end ring surfaces of the first valve sleeve 621 and the second valve sleeve 622. Preferably, the annular reinforcing push block 626 is connected to the end of the second valve core 624 away from the first valve core 623 through the L-shaped linkage rod 627 that can axially slide through the second valve sleeve 622. Thus, the annular partition cavity defined by the valve housing cylinder 61, the first valve core 623, the second valve core 624, and the elastic diaphragm 625 can jointly form a bypass flow guiding auxiliary cavity structure linked to the second valve core 624 with the annular reinforcing push block 626 and the L-shaped linkage rod 627. That is, the supplementary liquid flow supply action of the bypass flow guiding auxiliary cavity structure is associated with the movement of the second valve core 624, and the bypass flow channel formed by the bypass flow guiding auxiliary cavity structure is in parallel with the diversion channel. Specifically, the annular reinforcing push block 626 can synchronously move following the second valve core 624 under the traction of the L-shaped linkage rod 627. Thus, when the valve body structure formed by the second valve core 624 and the second valve sleeve 622 can be variably conducted, the annular reinforcing push block 626 can synchronously change the volume of the annular partition cavity and the shape of the elastic diaphragm 625, thereby realizing the follow-up reinforcement of the single-pulse liquid flow fluctuation generated when the diversion channel is conducted and improving the liquid flow pulse intensity. Preferably, a first elastic member 628 for limiting the initial insertion position of the second valve core 624 in the second valve sleeve 622 is further sleeved on the second valve core 624. Preferably, sealing washers are provided between the first valve sleeve 621 and the first valve core 623, and between the second valve sleeve 622 and the second valve core 624 to fill the assembly gap, avoiding the overflow of liquid flow while ensuring the relative movability between the two.

[0029] Preferably, a plurality of diversion through-holes 6211 corresponding to the first through-holes 611 one by one are formed in the side wall of the first valve sleeve 621. Preferably, a receiving step 6212 for accommodating the annular reinforcing push block 626 is formed on one side of the first valve sleeve 621 close to the second valve sleeve 622. Specifically, the receiving step 6212 of the first valve sleeve 621 can cooperate with the inner wall of the valve housing cylinder 61 to form an annular placement groove for accommodating the annular reinforcing push block 626. Preferably, a sealing washer for filling the assembly gap between the first valve sleeve 621 and the first valve core 623 is arranged on the side of the diversion through-hole 6211 to prevent the drilling fluid from flowing into the assembly gap between the first valve sleeve 621 and the first valve core 623.

[0030] Preferably, a narrow-edge step 6221 is arranged in the through cavity of the second valve sleeve 622 for inserting the second valve core 624, so that the narrow-edge step 6221 cooperates with the second valve core 624 to define the working position of the first elastic member 628. Preferably, a sealing washer for filling the gap is also arranged on the inner wall surface of the through cavity of the second valve sleeve 622. Preferably, a first through-axis hole 6222 communicating with the annular body cavity and capable of outputting the reinforced drilling fluid flow in the annular body cavity and a second through-axis hole 6223 for movably inserting the L-shaped linkage rod 627 are formed in the second valve sleeve 622.

[0031] As Figure 4 and Figure 6As shown, on the side wall surface of the first valve core body 6231 of the first valve core 623, first lateral through holes 6232, second lateral through holes 6233, and third lateral through holes 6234 for inputting drilling fluid flow with gradually increasing cross-sectional areas of the holes are provided. Specifically, the first lateral through holes 6232, second lateral through holes 6233, and third lateral through holes 6234 are circumferentially spaced apart in a manner of staggered distribution within the same toroidal surface, that is, the three through-hole structures defined by the first lateral through holes 6232, second lateral through holes 6233, and third lateral through holes 6234 are equidistantly provided on the same annular side wall, making them adjacent to each other in pairs. Preferably, the first lateral through holes 6232, second lateral through holes 6233, and third lateral through holes 6234 are strip-shaped hole cavity channels with gradually increasing flow guiding cross-sections. Specifically, the hole body widths of the first lateral through holes 6232, second lateral through holes 6233, and third lateral through holes 6234 are equal, and the ratio of the hole body lengths of the three is 1:2:3, so that the three allow different flow rates to pass through, enabling different intensities of liquid flow fluctuations to be generated when different through-hole structures are conducted. By using these liquid flow fluctuations to form different intensities of liquid flow pulses, liquid flow pulses with different peaks can cooperate with each other for communication programming, achieving more accurate and rapid data transmission with fewer pulse fluctuation times. Preferably, a first central vertical through hole 6235 for outputting drilling fluid flow and capable of communicating with the first lateral through holes 6232, second lateral through holes 6233, and third lateral through holes 6234 simultaneously is provided in the center of the end surface of the first valve core body 6231 facing the second valve core 624. Preferably, a one-way valve for limiting the one-way flow of the liquid flow is provided in the first central vertical through hole 6235. Specifically, this one-way valve limits the liquid flow to only flow into the first central vertical through hole 6235 from the first lateral through holes 6232, second lateral through holes 6233, or third lateral through holes 6234. Preferably, one end of the first valve core body 6231 away from the second valve core 624 is connected to a transmission assembly 65 capable of driving it to rotate around the axis.

[0032] As Figure 5As shown, on the end face of the second spool body 6241 of the second spool 624 facing the first spool body 6231, a second central vertical through hole 6242 for inputting drilling fluid flow is provided. Further preferably, on the side surface of the second spool body 6241, a plurality of fourth transverse through holes 6243 communicating with the second central vertical through hole 6242 and outputting drilling fluid flow are provided in a rotationally symmetric manner. Preferably, the fourth transverse through hole 6243 has a long-strip-shaped hole cavity cross-section, so that it can follow the lifting movement of the second spool body 6241 to change the cross-sectional size of the actually conducting hole cavity, thereby adjustably communicating with the cavity of the valve housing cylinder 61 below the second valve sleeve 622 to form diversion channels of different sizes, so that the size of the actually output pulsed fluid flow changes, and thus pulsed fluid flow fluctuations of different amplitudes are generated. Preferably, a first elastic member 628 capable of defining its initial working position inserted in the second valve sleeve 622 is sleeved outside the second spool body 6241. Preferably, a one-way valve for restricting the one-way flow of the fluid is further provided in the second central vertical through hole 6242, so that the fluid can only flow from the second central vertical through hole 6242 to the fourth transverse through hole 6243. Preferably, sealing washers for filling the insertion gap are sleeved above and below the fourth transverse through hole 6243 to prevent drilling mud from invading the installation space of the first elastic member 628, ensure the stability and effectiveness of the elastic expansion and contraction of the first elastic member 628, and prevent adhesion of the mud and ineffective expansion and contraction. Preferably, the axially lower end of the second spool body 6241 away from the first spool body 6231 is further connected to an L-shaped linkage rod 627, so that the L-shaped linkage rod 627 moves synchronously.

[0033] Specifically, in the actual working process, with the selective conduction of the first transverse through hole 6232, the second transverse through hole 6233 or the third transverse through hole 6234, there are differences in the flow rate in the diversion channel and the downward pressure received by the second spool body 6241. Therefore, the second spool body 6241 descends to different degrees at different speeds, and the limiting support spring represented by the first elastic member 628 is also compressed equally under the condition of the same compression deformation speed. At the same time, the annular reinforcement push block 626 will also be synchronously pulled to move equivalently. For example, when the first transverse through hole 6232 is conducting, the instantaneous hydraulic pressure increment in the diversion channel is small at this time, the second spool body 6241 descends slightly, and is elastically restricted by the first elastic member 628, and its descending speed is also slow. The equivalent movement amount and speed of the annular reinforcement push block 626 are small, and the supplement amount is general, which improves the output fluctuation of the actually formed pulsed fluid flow to a certain extent.

[0034] When the second transverse through hole 6233 is connected, the instantaneous hydraulic pressure increment of the diversion channel is moderate, and the second valve core body 6241 drops moderately. At this time, the downward thrust generated is also increased, so that the descending speed of the second valve core body 6241 increases, so that the annular reinforcement push block 626 generates a moderate amount of liquid flow supplement when the equivalent movement occurs, which greatly improves the output fluctuation of the actual pulse liquid flow.

[0035] When the third transverse through hole 6234 is connected, the instantaneous hydraulic pressure increment of the diversion channel is large, and the downward thrust applied to the second valve core body 6241 is significantly increased, causing the second valve core body 6241 to drop significantly, and its dropping speed is greatly increased compared with the aforementioned process, so that the annular reinforcement push block 626 generates a large amount of liquid flow supplement when an equivalent movement occurs in conjunction with the rise and fall of the second valve core body 6241, which greatly improves the output fluctuation of the actual pulse liquid flow, forcing the liquid in its chamber to be output from the first through-axis hole 6222 at a faster flow rate, thereby improving the reinforcement effect of the pulse liquid flow.

[0036] The pulse generating module 6 provided in the present application can controllably adjust the conduction of different cross-sectional sizes, thereby forming liquid flow fluctuations of different sizes, so that the pulse peak corresponding to a single liquid flow fluctuation has different sizes and amplitudes, thereby defining pulse signals in different frequency gradient ranges. Specifically, the variable multi-level pulse signal means that the axial hole cavities actually conducted by the first valve core body 6231 at different time nodes during controllable rotation are different, thereby constructing a flow channel with different actual diversion volume, input liquid flow impulse, and hydraulic instantaneous increment. Therefore, the pulse signals transmitted by the liquid flow fluctuations corresponding to these time nodes are also different, thereby variably forming pulse signals of multiple levels of different intensities and different frequency bands. Preferably, the adjustable flow cross-section and intermittent opening and closing means that the control unit 67 controls the driving unit 66 to rotate, driving the first valve core body 6231 to rotate controllably, so that the first transverse through hole 6232, the second transverse through hole 6233 or the third transverse through hole 6234 are selectively connected, constructing a guide channel with a minimum flow cross-section of different sizes, forming a pulse liquid flow of different intensities, and in the above-mentioned change process, the adjustment and transformation of the flow cross-section is realized, and in the process of changing the size of the flow cross-section, the first valve core body 6231 realizes the conduction switching of the first transverse through hole 6232, the second transverse through hole 6233, and the third transverse through hole 6234 by rotation. The intermittent period of the above-mentioned switching cannot form a smooth flow channel, and the switching of the flow channel realizes the intermittent opening and closing of the flow channel. Specifically, the diversion channel refers to the hollow cylindrical cavity formed by the first through-hole 611, the diversion through-hole 6211, the first central vertical through-hole 6235, the elastic diaphragm 625, the second central vertical through-hole 6242, and the fourth transverse through-hole 6243, through which the drilling fluid can pass in sequence, wherein the diversion through-hole 6211 and the first central vertical through-hole 6235 are connected through the first transverse through-hole 6232, the second transverse through-hole 6233, or the third transverse through-hole 6234, forming a through-channel cavity for the fluid to pass through. Specifically, the pulsed fluid flow with controllable intensity refers to the minimum flow cross-section of different sizes defined when the diversion channel presents different conduction states, the corresponding peak value of the fluid flow fluctuation is controllably changed, and the intensity of the pulsed fluid flow formed can be effectively controlled and regulated. Specifically, the bypass diversion sub-cavity structure composed of the annular partition cavity, the annular reinforcement push block 626, and the L-shaped linkage rod 627 can be linked with the lifting and lowering movement of the second valve core 624. While the diversion channel intermittently outputs pulse liquid flow, the bypass diversion sub-cavity can also synchronously output an additional reinforcement liquid flow. The two liquid flows can converge in the bottom section of the valve shell cylinder 61 to form a stronger pulse fluctuation, thereby improving the strength and noise resistance of the pulse signal.

[0037] Preferably, when the first spool body 6231 rotates driven by the driving unit 66, the settings of its rotation period, intermittent frequency, speed, and movement direction will change the intensity and peak value of the single-pulse fluctuation as well as the number and frequency of the pulse fluctuations in a single cycle, so that a variety of different pulse signals can be controllably generated to achieve the effective transmission of different data. Specifically, the three sequentially intermittently conducting diversion channels defined by the single rotation of the first spool body 6231 correspond to the single signal carriers of 01, 02, and 03; when the continuously two intermittently conducting liquid flow fluctuations are used as a group of signal carriers, they can be two-arrangement signal carriers such as 0101, 0102, 0103, 0202, 0203, 0201, 0303, 0301, 0302, and so on. By analogy, the signal carriers can also be three-arrangement or four-arrangement, etc., and during the process of the above fluctuations, the combinability of modulation communication can be increased by defining different gap periods, so as to characterize more well deviation parameters through short pulse fluctuations, shorten the total number of pulse fluctuations and the length of the fluctuation period, and improve the efficiency and speed of communication.

[0038] Preferably, sliding packing washers are provided on both the inner ring surface and the outer ring surface of the annular reinforcing push block 626 to ensure the effective fitting of the annular reinforcing push block 626 and the elastic diaphragm 625. The downward-moving annular reinforcing push block 626 pushes the liquid in the ring body cavity out of the first through-hole 6222 effectively in the manner of forming a piston body. Preferably, the axially translating annular reinforcing push block 626 can scrape and push back the elastic diaphragm 625 during its downward movement, so that the elastic diaphragm 625 that is driven by the increased hydraulic pressure in the diversion channel and expands radially outward is limited by the annular reinforcing push block 626, realizing radial inward contraction. The volume of the section chamber defined by the elastic diaphragm 625 decreases, forcing the liquid flow in this section chamber to be output under a greater hydraulic pressure state, further enhancing the pulse intensity and peak value. Preferably, the elastic diaphragm 625 is in the form of a frustum-shaped ring wall, that is, the circular end face of the elastic diaphragm 625 connected to the first valve sleeve 621 is smaller than the circular end face connected to the second valve sleeve 622, which is convenient for the annular reinforcing push block 626 moving towards the second valve sleeve 622 to effectively scrape and compress the elastic diaphragm 625, so that the elastic diaphragm 625 can be more effectively constrained inward by the descending annular reinforcing push block 626, enhancing the pressurization effect and strength of the section chamber it defines.

[0039] Preferably, the sealed connection assembly 63 includes a sealed connection cylinder 631, a rotating shaft sleeve 632, and a limiting bearing 633. Preferably, both ends of the sealed connection cylinder 631 are respectively connected to the valve housing cylinder 61 and the mounting sleeve 64, and the rotating shaft sleeve 632 is inserted into the sealed connection cylinder 631. Preferably, a limiting bearing 633 is sleeved on the rotating shaft sleeve 632 for defining a coaxial plug connection mode in which the sealed connection cylinder 631 and the rotating shaft sleeve 632 can rotate relative to each other. Specifically, the inner ring of the limiting bearing 633 is fixedly connected to the outer ring of the rotating shaft sleeve 632, and the outer ring of the limiting bearing 633 is fixedly connected to the inner ring of the sealed connection cylinder 631. Further preferably, a plurality of sealing washers for filling the assembly gap are provided between the inner wall of the sealed connection cylinder 631 and the outer wall of the rotating shaft sleeve 632 to prevent drilling fluids such as mud from overflowing into the assembly gap. Further preferably, a plurality of sealing washers are also embedded on the inner wall of the rotating shaft sleeve 632, so as to fill the assembly gap between the rotating shaft sleeve 632 and the drive shaft rod 651 and prevent the intrusion of drilling fluid into the drive unit 66.

[0040] Preferably, the transmission assembly 65 includes a drive shaft rod 651, a reducer 652, and a coupling 653. Preferably, the drive shaft rod 651 is inserted into the rotating shaft sleeve 632. The upper end of the drive shaft rod 651 in the axial direction is connected to a reducer 652. Further preferably, the upper end of the reducer 652 away from the drive shaft rod 651 in the axial direction is in transmission connection with the coupling 653. Specifically, the drive shaft rod 651 and the output shaft of the reducer 652 are assembled in a transmission manner by means of a shaft sleeve connection. Specifically, the reducer 652 can be a reduction drive structure with a large reduction ratio. For example, its reduction ratio can be 1:600. The rotation of the servo motor can actually output a small deflection of the drive shaft rod 651, which is convenient for constructing different conduction channels according to requirements, forming pulse fluctuations of different intensities, and forming a pulse signal through the combination of multiple different pulse fluctuations, shortening the total number of pulse fluctuations and the length of the fluctuation period, and realizing the efficient characterization of detection data by using the combination of short multi-band pulse fluctuations. Specifically, the coupling 653 and the input shaft of the reducer 652 are in transmission connection by means of a key connection or a tight fit, and a lock washer is also installed to prevent the bolt from loosening. Preferably, the coupling 653 is an elastic coupling, which can well transmit torque and prevent damage to the transmission structure caused by instantaneous or short-term abnormalities such as transmission jamming.

[0041] Preferably, the driving unit 66 is a servo motor capable of continuously rotating forward with adjustable speed according to requirements, or rotating forward and backward with adjustable single rotation amount and alternately, and staggered. Preferably, the output shaft of the driving unit 66 is in transmission connection with the coupling 653, and the terminal of the driving unit 66 is connected to the driving circuit unit corresponding to the control unit 67. Preferably, the control unit 67 is a driving circuit unit jointly composed of a motor control circuit, a power supply circuit board, etc., which can control the servo motor represented by the driving unit 66 and set working parameters, and limit the rotation direction, rotation speed, rotation time, interval time, etc. of the servo motor. Specifically, the driving unit 66 and the control unit 67 are also connected to the measurement-while-drilling module 4 through an internal cable passing through the centralizer 2 and the flexible hinge joint 5 to achieve power supply and communication. Preferably, the power supply unit 43 is connected to the driving unit 66 and the control unit 67 through a cable to supply power to both. Preferably, the inclinometer 41 and the gyro detection unit 42 while drilling are connected to the control unit 67 through a communication cable, and the control unit 67 can generate pulse commands consistent with the actual drilling parameters according to the data collected by the inclinometer 41 and the gyro detection unit 42 while drilling, and then effectively transmit the underground drilling data by using the drilling fluid flow returning to the surface.

[0042] Preferably, the control unit 67 includes a connector and a circuit board. The connector is used to connect the inclinometer 41 and the gyro detection unit 42 while drilling. The circuit board is equipped with software programs to calculate and analyze the data collected by the inclinometer 41 and the gyro detection unit 42 while drilling, and compare and verify the well inclination parameters collected by the inclinometer 41 and the gyro detection unit 42 while drilling that independently collect data from each other, so as to supplement missing data and correct some distorted data, generate well inclination data closest to the actual drilling situation, and improve the quality and accuracy of the data output by pulse communication. Preferably, the control unit 67 can output control commands according to the processed well inclination data to modulate the motion parameters of the driving unit 66. Specifically, the adjustment of the motion parameters means that the control unit 67 can set the rotation speed, rotation amount and rotation direction of the driving unit 66, that is, the motion parameters mainly refer to the rotation speed, rotation amount and rotation direction of the servo motor represented by the driving unit 66, so that the driving unit 66 can continuously and directionally perform variable-frequency rotation and / or alternately positive and negative quantitative deflection, so that the first lateral through hole 6232, the second lateral through hole 6233 and the third lateral through hole 6234 are selectively conducted, and the conduction sequence and conduction interval duration can be limited according to requirements, so that the liquid flow fluctuation formed by intermittent conduction can generate a pulse signal corresponding to the well inclination data.

[0043] Preferably, the present application also provides a method for measuring well inclination while drilling with multi-band pulse communication, which includes the following steps: The detection while drilling module 4 can collect the well deviation data of the drilling section, and the collected data is transmitted to the control unit 67 via the cable; The control unit 67 generates a control instruction based on the detection data, controls the drive unit 66 to rotate with the motion parameters changed according to the instruction, and the rotational motion of the drive unit 66 is transmitted to the first valve core 623 of the valve head assembly 62 through the transmission assembly 65, so that the valve head assembly 62 cooperates with the valve shell tube 61 to construct a guide channel with adjustable flow cross-section and intermittent opening and closing, thereby forming a pulsed liquid flow with variable intensity, and the valve head assembly 62 can also cooperate with the valve shell tube 61 to construct a bypass guide sub-cavity structure that supplies reinforcement liquid flow in association with the real-time conduction state of the guide channel.

[0044] The drilling detection module 4 collects well deviation data in real time through the drilling inclinometer 41 and the gyro detection unit 42, and the control unit 67 can compare and verify the well deviation data collected by the drilling inclinometer 41 and the gyro detection unit 42, thereby correcting the data deviation; The control unit 67 generates control instructions based on the corrected well deviation data and modulates the motion parameters of the drive unit 66 within a certain period, causing the drive unit 66 to perform periodic motion according to the set motion parameters, driving the first valve core 623 to perform synchronous motion, forming a diversion channel with an adjustable flow cross-section and intermittent opening and closing. This then generates pulsed liquid flows of varying intensity based on the diversion channel, and utilizes liquid flow fluctuations with varying intensities and peak values to generate multi-band pulse signals, achieving efficient and convenient characterization of the well deviation data. While the diversion channel is connected and liquid flow fluctuations are formed, the bypass diversion sub-cavity structure synchronously supplies reinforcing liquid flow, further enhancing the intensity and peak value of the pulsed liquid flow fluctuations, thereby increasing the noise immunity and communication characterization quality of the pulse communication.

[0045] The present invention is not limited to the above-mentioned optional implementation modes. Anyone can derive other forms of products under the inspiration of the present invention. However, no matter what changes are made in the shape or structure, any technical solution that falls within the scope defined by the claims of the present invention falls within the protection scope of the present invention. Those skilled in the art should understand that the description of the present invention and its drawings are illustrative and do not constitute a limitation on the claims. The scope of protection of the present invention is defined by the claims and their equivalents. Throughout the text, the features guided by "preferably" are only an optional method and should not be understood as having to be set. Therefore, the applicant reserves the right to abandon or delete the relevant preferred features at any time.

Claims

1. A measurement-while-drilling device for multi-band pulse communication, comprising a housing tube (3) connected to a fishing head (1) through a centralizer (2), characterized in that, a measurement-while-drilling detection module (4) capable of monitoring real-time parameters of drilling is arranged in the housing tube (3); one end of the housing tube (3) far from the fishing head (1) is connected to a pulse generating module (6) capable of outputting a pulse signal according to real-time detection data obtained by the measurement-while-drilling detection module (4) through a series-connected centralizer (2) and a flexible hinge joint (5); a valve head assembly (62) of the pulse generating module (6) forms a pulse liquid flow with variable intensity in such a way that it can construct a diversion channel with an adjustable flow passage cross-section and intermittent opening and closing in a valve housing cylinder (61), and the valve head assembly (62) can also cooperate with the valve housing cylinder (61) to construct a bypass diversion sub-chamber structure for supplying a reinforcing liquid flow associated with the real-time conduction state of the diversion channel.

2. The measurement-while-drilling inclinometer for multi-band pulse communication according to claim 1, wherein The valve housing cylinder (61) is connected to an installation sleeve (64) through a sealing connection assembly (63), and a valve head assembly (62) capable of having a relative position change is inserted in the valve housing cylinder (61); the valve head assembly (62) is connected to a driving unit (66) installed in the installation sleeve (64) through a transmission assembly (65) that movably passes through the sealing connection assembly (63), and a control unit (67) for setting the motion parameters of the driving unit (66) is also arranged in the installation sleeve (64).

3. The wired drill inclinometer device for multi-band pulse communication according to claim 2, wherein A first valve sleeve (621) and a second valve sleeve (622) of the valve head assembly (62) are inserted into the valve housing cylinder (61) at intervals, and a first valve core (623) and a second valve core (624) are respectively movably inserted into the valve body cavities of the first valve sleeve (621) and the second valve sleeve (622); an elastic diaphragm (625) capable of cooperating with the valve housing cylinder (61) to form an annular partition cavity is also arranged between the first valve sleeve (621) and the second valve sleeve (622), and an annular reinforcing push block (626) capable of axially moving is also arranged in the annular partition cavity; the annular reinforcing push block (626) is connected to the second valve core (624) through an L-shaped linkage rod (627) passing through the second valve sleeve (622).

4. The measurement-while-drilling inclinometer for multi-band pulse communication according to claim 3, wherein Circumferentially spaced-apart first lateral through holes (6232), second lateral through holes (6233), and third lateral through holes (6234) are formed on the side wall surface of a first valve core main body (6231) of the first valve core (623); a first central vertical through hole (6235) capable of communicating with the first lateral through hole (6232), the second lateral through hole (6233), and the third lateral through hole (6234) at the same time is formed on the end surface of the first valve core main body (6231) facing the second valve core (624).

5. The wired drill inclinometer for multi-band pulse communication according to claim 4, wherein A second central vertical through hole (6242) is provided on the end surface of the second valve core body (6241) of the second valve core (624) facing the first valve core body (6231), and a plurality of fourth transverse through holes (6243) communicating with the second central vertical through hole (6242) are provided on the side surface of the second valve core body (6241) in a rotationally symmetrical manner.

6. The measurement-while-drilling inclinometer for multi-band pulse communication according to claim 5, characterized in that, A first elastic member (628) is also sleeved on the outer side of the second valve core body (6241) to define its initial insertion position in the second valve sleeve (622).

7. The measurement-while-drilling device for multi-band pulse communication according to claim 6, wherein, The two ends of the sealing connection cylinder (631) of the sealing connection assembly (63) are respectively connected to the valve housing cylinder (61) and the installation sleeve (64), and a rotating shaft sleeve (632) is inserted into the sealing connection cylinder (631). A limiting bearing (633) is sleeved on the rotating shaft sleeve (632) to define a relatively rotatable connection between the rotating shaft sleeve (632) and the sealing connection cylinder (631).

8. The wired drill inclinometer for multi-band pulse communication according to claim 7, characterized in that, The axial lower end of the transmission shaft (651) of the transmission assembly (65) is connected to the first valve core body (6231), the transmission shaft (651) is inserted into the rotating shaft sleeve (632), and the axial upper end of the transmission shaft (651) is connected to a reducer (652); the reducer (652) is transmission-connected to the coupling (653) at the axial upper end away from the transmission shaft (651).

9. A method for measuring inclination while drilling with multi-band pulse communication, including the device for measuring inclination while drilling with multi-band pulse communication according to the preceding claim 8, characterized in that, The following steps are also included: The detection while drilling module (4) is capable of collecting well deviation data during the drilling process, and the collected data is transmitted to the control unit (67) via a cable; The control unit (67) generates a control instruction based on the detection data, thereby controlling the drive unit (66) to rotate according to the instruction so as to change the motion parameters, and the rotational motion of the drive unit (66) is transmitted to the first valve core (623) of the valve head assembly (62) through the transmission assembly (65), so that the valve head assembly (62) cooperates with the valve shell cylinder (61) to construct a diversion channel with an adjustable flow cross-section and intermittent opening and closing, thereby forming a pulsed liquid flow with variable intensity, and the valve head assembly (62) can also cooperate with the valve shell cylinder (61) to construct a bypass diversion sub-cavity structure for supplying a reinforcement liquid flow in association with the real-time conduction state of the diversion channel.

10. The method for measuring inclination while drilling in multi-band pulse communication according to claim 9, characterized in that, The drilling detection module (4) collects well inclination data in real time through the drilling inclinometer (41) and the gyro detection unit (42), and the control unit (67) can compare and verify the well inclination data collected by the drilling inclinometer (41) and the gyro detection unit (42), thereby correcting data deviation.

Images