A multi-band pulse communication while drilling inclination measurement device and method

Abstract

The present invention relates to a multi-band pulse communication while-drilling inclination measurement device and method, and relates to the technical field of while-drilling inclination measurement equipment. A fishing head is connected to an outer shell tube through a stabilizer, and a while-drilling detection module for monitoring drilling conditions is provided in the outer shell tube. The outer shell tube is also connected to a pulse generating module through a series-connected stabilizer and a flexible hinge joint. The valve head assembly of the pulse generating module forms a pulse liquid flow with variable intensity by constructing a diversion channel with an adjustable flow cross-section and intermittent opening and closing in the valve shell tube. The valve head assembly also cooperates with the valve shell tube 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. The present invention can adjustably generate pulse signals of multiple frequency bands, thereby improving the efficiency of pulse communication and shortening the data transmission cycle. It also supplies a reinforcement liquid flow in a linkage manner to increase the intensity of the pulse liquid flow, thereby improving the noise resistance and transmission quality of the pulse signal.

Description

Technical Field

[0001] The present invention relates to the technical field of measurement-while-drilling equipment, and in particular to a measurement-while-drilling device and method with 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 reservoir position and the drilling route. The early traditional measurement method was for operators to place detection equipment along the drilling channel into the well via cables or optical cables to regularly measure the drilling trajectory at the bottom of the well. However, this testing method cannot effectively deliver the detection equipment to the bottom of the well in inclined wells, and effective measurement cannot be achieved. In addition, the well wall is prone to collapse or blockage due to geological conditions and other issues, which will also affect the logging work. On the other hand, since drilling fluid needs to be continuously added during the drilling process, the drilling fluid carries the rock cuttings destroyed by drilling and production from the bottom of the well to the surface. The drilling fluid will gradually invade the rock wall during the circulation process. Therefore, when testing is carried out after drilling and production is completed, the drilling fluid will cause a certain degree of interference with the various parameters of the formation. In order to improve the quality and accuracy of detection, measurement while drilling technology has gradually been developed, replacing traditional measurement methods. The detection equipment descends simultaneously with the drill bit in the well, realizing the collection of information such as drilling inclination and drilling trajectory, and then using the measured drilling parameters and formation parameters to adjust the drill bit trajectory in time to ensure drilling accuracy.

[0003] Currently, measurement-while-drilling (MWD) and logging-while-drilling (LWD) tools are becoming increasingly common. Whether it's drilling engineering parameters measured by MWD and LWD, such as wellbore inclination data, geological parameters, formation gamma counts, resistivity values, and acoustic wave data, or other parameters measured by rotary geosteering tools, they all need to be transmitted from the mud to the surface system via a pulse signal generator. The surface system collects the waveform output by the pulse signal generator through a pressure sensor on the drilling riser, decodes it, and restores it to downhole engineering and geological parameters in real time. However, the pulse signal generators of existing while-drilling detection tools typically use the principle of a small solenoid valve driving a large valve to generate pulsed liquid flow. While the pulse signal corresponding to the pulsed liquid flow can be used for data transmission, it suffers from long travel time, low baud rate for data transmission, and poor practicality. In particular, with the increase in drilling depth and the increasing complexity of the downhole environment, the high power consumption and low tension of the solenoid valve can no longer meet the use requirements and cannot be effectively applied to harsh working conditions. Under this condition, the rotary valve pulser can be used in high-temperature environments, and the low-power motor improves the battery life and anti-electromagnetic interference. The driving force and service life of the motor are much greater than those of the electromagnetic coil. In addition, the use of the rotary valve eliminates the oil filling link of the pulser, shortens the production and maintenance time, and is therefore 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: a multi-band pulse communication while drilling inclination measurement device, including an outer shell tube connected to a fishing head through a stabilizer, a while drilling detection module capable of monitoring real-time drilling parameters is arranged in the outer shell tube, and the end of the outer shell tube away from the fishing head is connected to a pulse generation module capable of outputting pulse signals based on real-time detection data obtained by the while drilling detection module through a stabilizer and a flexible hinged joint connected in series. The valve head assembly of the pulse generation module is capable of forming a pulse liquid flow with variable intensity in a manner that can construct a diversion channel with adjustable flow cross-section and intermittent opening and closing in the valve shell tube. The valve head assembly can also cooperate with the valve shell tube 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. Its advantage is that the pulse generating module provided in the present application utilizes the cooperation of the valve head assembly and the valve housing to adjustably construct a plurality of conducting flow channels with different minimum flow cross-sections. When different conducting flow channels are connected separately, liquid flow fluctuations with different instantaneous hydraulic increments and different peak values ​​can be generated in the conducting flow channels, so that the intensity of the formed pulse liquid flow is different, and the frequency bands of the corresponding pulse signals can also be defined differently to realize the controllable formation of multi-band pulse signals, thereby facilitating the efficient characterization of well inclination data quickly and accurately, improving the quality and accuracy of data transmission, improving the effect of data feedback and the efficiency of data transmission, and shortening the data transmission cycle. The bypass diversion sub-cavity structure set up in the present application can supply reinforcing liquid flow in association with the instantaneous flow rate of the pulse liquid flow, thereby increasing the liquid flow fluctuation peak and the overall strength of the pulse liquid flow, improving the noise anti-interference ability of the pulse liquid flow during transportation in the drilling well and reducing the impact of energy attenuation during the transportation process, ensuring that the final output pulse liquid 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.

[0007] According to a preferred embodiment, the valve housing is connected to the mounting sleeve via a sealing connection assembly, and a valve head assembly capable of relative position change is inserted into the valve housing. The valve head assembly is connected to a drive unit mounted in the mounting sleeve via a transmission assembly that moves 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. The advantage is that the pulse generation module provided in this application can improve the efficiency and quality of communication by increasing the communication frequency band and improving the pulse intensity, thereby 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 axial lower end of the transmission shaft of the transmission assembly is connected to the first valve core body, the transmission shaft is inserted into the rotating shaft sleeve, and the axial upper end of the transmission shaft is connected to a reducer; the reducer is away from the axial upper end of the transmission shaft and is transmission-connected to the coupling.

[0014] The present invention also provides a method for measuring inclination while drilling using multi-band pulse communication, comprising the aforementioned device for measuring inclination while drilling using multi-band pulse communication, and further comprising the following steps:

[0015] The detection while drilling module can collect the well deviation data of the drilling section, and the collected data is transmitted to the control unit via the cable;

[0016] The control unit generates a control instruction based on the detection data, thereby controlling the drive unit to rotate according to the instruction with a change in motion parameters, and the rotational motion of the drive unit is transmitted to the first valve core of the valve head assembly through the transmission assembly, so that the valve head assembly cooperates with the valve shell barrel to construct a guide 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 can also cooperate with the valve shell barrel to construct a bypass guide sub-cavity structure for supplying a reinforcement liquid flow in association with the real-time conduction state of the guide channel.

[0017] According to a preferred embodiment, the drilling detection module collects well deviation data in real time through a drilling inclinometer and a gyro detection unit, and the control unit can compare and verify the well deviation data collected by the drilling inclinometer and the gyro detection unit, thereby correcting data deviation.

[0018] The beneficial effects of the present invention are:

[0019] The pulse generating module provided in the present application utilizes the cooperation between the valve head assembly and the valve housing to adjustably construct a plurality of conducting flow channels with different minimum flow cross-sections. When different conducting flow channels are connected separately, liquid flow fluctuations with different instantaneous hydraulic increments and different peak values ​​can be generated in the conducting flow channels, so that the intensity of the formed pulse liquid flow is different, and the frequency bands of the corresponding pulse signals can also be defined differently to realize the controllable formation of multi-band pulse signals, thereby facilitating the efficient characterization of well inclination data quickly and accurately, improving the quality and accuracy of data transmission, improving 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 timely and accurate adjustment of drilling processes.

[0020] 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

[0021] 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;

[0022] 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;

[0023] 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;

[0024] 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 A in the middle;

[0025] 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;

[0026] 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;

[0027] 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.

[0028] Reference Signs List

[0029] 1: Fishing head; 2: Centralizer; 3: Housing tube; 4: Detection while drilling module; 5: Flexible articulated joint; 6: Pulse generating module; 41: Detection while drilling inclinometer; 42: Gyro detection unit; 43: Energy supply unit; 61: Valve housing; 62: Valve head assembly; 63: Sealing connection assembly; 64: Mounting sleeve; 65: Transmission assembly; 66: Drive unit; 67: Control unit; 611: First through-hole; 612: Second through-hole; 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-hole; 6212: accommodating step; 6221: narrow side step; 6222: first through-axis hole; 6223: second through-axis 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: fourth transverse through-hole; 6243: second central vertical through-hole; 631: sealing connection cylinder; 632: rotating shaft sleeve; 633: limit bearing; 651: transmission shaft; 652: reducer; 653: coupling. DETAILED DESCRIPTION

[0030] The following is a detailed description with reference to the accompanying drawings.

[0031] The present application provides a multi-band pulse communication while drilling inclination measurement device, which includes a fishing head 1, a stabilizer 2, an outer shell tube 3, a while drilling detection module 4, a flexible articulated head 5 and a pulse generation module 6.

[0032] according to Figure 1 and Figure 2In a specific embodiment shown, a fishing head 1 is connected to a housing tubular 3 via a centralizer 2. A detection-while-drilling (DWD) module 4 is located within the housing tubular 3, capable of monitoring real-time parameters such as wellbore inclination data in the drilling section. The end of the housing tubular 3, remote from the fishing head 1, is connected to a pulse generator 6 via a series connection of the centralizer 2 and a flexible articulated joint 5. The pulse generator 6 generates control instructions based on the real-time detection data collected by the DWD module 4 and outputs variable multi-level pulse signals based on the control instructions. The valve head assembly 62 of the pulse generator 6 generates a pulsed flow with controllable intensity by constructing a diversion channel with adjustable flow cross-section and intermittent opening and closing within the valve housing 61, thereby controllably outputting multi-level pulse signals. Furthermore, the valve head assembly 62 cooperates with the valve housing 61 to construct a bypass diversion sub-chamber structure that supplies a reinforcement flow in accordance with the real-time conduction state of the diversion channel. The valve head assembly 62 provided in the present application can form a variety of conduction channels with different minimum flow cross-sections according to the needs. When different conduction channels are connected, a flow channel with a minimum flow cross-section can be generated. Different instantaneous hydraulic pressure increments and different peak flow fluctuations make the pulses The intensity of the flushing flow varies, and the frequency bands of the corresponding pulse signals can also be defined differently to achieve multi-band pulse signals. The controllable formation facilitates the efficient characterization of well deviation data quickly and accurately, improving the quality and accuracy of data transmission. Improves the effect of data feedback and the timeliness of data during pulse communication, making it convenient to carry out drilling processes in a timely and accurate manner Adjustment The bypass diversion sub-cavity structure provided in this application can be combined with the pulse flow Supply and replenishment in relation to the instantaneous flow rate Strong liquid flow, increase the liquid flow fluctuation peak and the overall strength of the pulse liquid flow, improve the stability and noise resistance of the pulse signal, and improve It characterizes the accuracy and integrity of data, reduces the risk of pulse signal distortion and loss, and reduces energy consumption during transmission. The impact of quantity attenuation is effectively defined and maintained at multiple discrete and reliable pulse flow pressure levels, making it convenient for Pulse flow of the same intensity can achieve high-quality transmission of pulse signals of different frequency bands, enabling the ground system to effectively identify Don't .

[0033] Preferably, the salvage head 1 is connected to the stabilizer 2 in a detachable manner such as a set / insert, so that the salvage head 1 can be easily assembled with the main body of the while-drilling inclinometer string, ensuring the convenience of assembly and disassembly and the stability of the connection. The salvage head 1 is located at the axial upper end of the while-drilling inclinometer device, so that it can be easily salvaged and connected by external equipment. Specifically, the salvage head 1 can directly refer to the relevant components in the existing patent with publication number CN114658419A. Preferably, the stabilizer 2 adopts a sealed connecting sleeve structure and a roller that is arranged on the side of the connecting sleeve annulus and can rotate. Specifically, a number of rollers are arranged circumferentially at intervals, so that the interior of the connecting sleeve structure can be easily threaded. Preferably, both ends of the outer shell tube 3 are connected to the stabilizer 2, so that the inner cavity of the pipe string is connected, which facilitates the cable connection between the while-drilling detection module 4 and the pulse generation module 6, and facilitates energy and information transmission between the two. Specifically, the outer shell tube 3 has internal threads and fixed ring stoppers and other limiting structures to facilitate the fixed installation of the drilling detection module 4, so that the drilling detection module 4 can be detachably installed in the outer shell tube 3, avoiding relative movement between the drilling detection module 4 and the outer shell tube 3, and improving the installation stability and structural connection strength. Preferably, a sealing plate is provided in the upper inner cavity of the outer shell tube 3, which is used to separate its inner chamber to avoid abnormal liquid intrusion at the end of the outer shell tube 3 close to the fishing head 1, thereby avoiding the risk of damaging the drilling detection module 4. Preferably, a sealing gasket is provided in the docking port of the centralizer 2 and the flexible hinged head 5 to ensure the closedness of the formed inner cavity space, avoid external liquid intrusion into the accommodating space, and ensure the isolation and safety of the drilling detection module 4 and the pulse generating module 6.

[0034] Preferably, the real-time parameters of drilling refer to well deviation data such as the well body inclination and drilling path of the latest drilling section formed during the drilling process of the drilling tool.

[0035] like Figure 2As shown, the drilling detection module 4 includes a drilling inclinometer 41, a gyro detection unit 42, and a power supply unit 43. Specifically, the drilling inclinometer 41, gyro detection unit 42, and power supply unit 43 are fixed to the inner wall of the outer casing 3 through locking and bolting methods. Preferably, the drilling inclinometer 41 consists of a probe tube and a gamma-ray integrated core structure. The gamma-ray integrated core structure is installed in the probe tube, and the probe tube is fixed in the outer casing 3 through a limit locking method. The gamma-ray probe has a counting range of 250 CPS, a sensitivity of 1.5 CPS / API, an accuracy of 5%, a resolution of 200 mm, a maximum temperature resistance of 150°C, a maximum pressure resistance of 140 MPa, a maximum allowable shock of 1000 G / 0.5 ms, and a maximum allowable vibration of 30 G / 50-300 Hz. Preferably, the gyro detection unit 42 consists of a probe tube, a circuit structure, and a sensor. The circuit structure and sensor are all located in the probe tube. The circuit structure mainly includes an acquisition and resolution circuit, a control and transmission circuit, etc. connected to the sensor. Preferably, the control transmission circuit of the gyro detection unit 42 is communicatively connected to the while-drilling inclinometer 41, allowing them to operate simultaneously or independently as needed. Preferably, the power supply unit 43 is connected to the while-drilling inclinometer 41 and the gyro detection unit 42 via a cable, enabling the power supply unit 43 to controllably supply power to the while-drilling inclinometer 41 and / or the gyro detection unit 42. Specifically, the data collected by the while-drilling inclinometer 41 and the gyro detection unit 42 can be compared and verified against each other, thereby improving the accuracy of the wellbore inclination parameters output as feedback through mutual compensation and correction of the collected data. Preferably, the gyro detection unit 42 includes a gyro sensor and a connector. The gyro sensor is mounted on a circuit support for data collection; the connector is mounted on the circuit support for connecting the power supply unit 43 to the control unit 67. The gyro sensor is capable of collecting drilling trajectory parameters within a measurement range of an inclination angle of 0±90°. This application changes the sensor from a traditional single-axis to a three-axis micro-mechanical gyro sensor. By calculating and analyzing the data collected by the three-axis sensor, the inclination angle, positioning angle, etc. are obtained, achieving operation within the measurement range of 0±90° inclination angle. Because the distance between the drilled wellbore and the adjacent well is small during the drilling process or operations need to be carried out in the casing, the casing will generate magnetic interference. When performing downhole measurement in these environments with magnetic interference, the wireless downhole instrument represented by the downhole inclinometer 41 based on magnetic measurement cannot be used normally. At this time, this application uses the gyro detection unit 42 to accurately measure the wellbore inclination parameters in an environment with magnetic field interference, thereby improving measurement accuracy and data quality, and ensuring the correctness of the operational adjustments made by ground feedback.

[0036] like Figure 2 、 Figure 3 and Figure 7As shown, the pulse generating module 6 includes a valve housing 61, a valve head assembly 62, a sealing connection assembly 63, a mounting sleeve 64, a transmission assembly 65, a drive unit 66, and a control unit 67. Preferably, the valve housing 61 is connected to the mounting sleeve 64 via the sealing connection assembly 63. Preferably, a valve head assembly 62 capable of generating a pulsed liquid flow by changing relative positions is inserted into the valve housing 61. Preferably, the valve head assembly 62 is connected to the drive unit 66 mounted in the mounting sleeve 64 via a transmission assembly 65 that moves through the sealing connection assembly 63. Further preferably, a control unit 67 that adjustably defines the motion parameters of the drive unit 66 is also provided in the mounting sleeve 64.

[0037] Preferably, a first through-hole 611 and a second through-hole 612 are provided on the sidewall of the valve housing 61, connecting the inside and outside of the housing. Preferably, multiple first through-holes 611 are provided in an circumferentially spaced arrangement on the section of the housing where the first valve sleeve 621 is inserted. Further preferably, multiple diversion through-holes 6211 are provided on the sidewall of the first valve sleeve 621, corresponding one-to-one with the first through-holes 611. Specifically, the first through-holes 611 and the diversion through-holes 6211 can be through-channels with rectangular cross-sections. Preferably, multiple second through-holes 612 are provided in an circumferentially spaced arrangement to enable communication with the annular compartment. Specifically, the second through-holes 612 can be through-channels with circular cross-sections to facilitate installation of the one-way valve. Preferably, a filter plate 613 capable of coarsely filtering the drilling fluid composed of drilling mud is embedded in both the first through-hole 611 and the second through-hole 612. Preferably, a one-way valve capable of limiting the drilling fluid flow to flow into the annulus compartment in one direction is further provided in the second through-hole 612 .

[0038] 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 reinforcement push block 626, an L-shaped linkage rod 627, and a first elastic member 628. Preferably, the surfaces of the first and second valve sleeves 621, 622 are spray-coated with cemented carbide to enhance wear resistance. Preferably, the first and second valve cores 623, 624 are made of cemented carbide to enhance wear and erosion resistance. Preferably, the first and second valve sleeves 621, 622 of the valve head assembly 62 are interposed within the valve housing 61, with the first and second valve cores 623, 624 movably mounted within the valve body cavities of the first and second valve sleeves 621, 622, respectively. Preferably, an elastic diaphragm 625 is disposed between the first and second valve sleeves 621, 622 to form an annular cavity in cooperation with the valve housing 61. Preferably, an annular reinforcing push block 626 capable of axial movement is also provided in the annular cavity. Specifically, the ends of the elastic diaphragm 625 made of wear-resistant rubber or wear-resistant silicone sheet and in the shape of a truncated cone ring wall are respectively connected to the end annular surfaces of the first valve sleeve 621 and the second valve sleeve 622. Preferably, the annular reinforcement push block 626 is connected to the end of the second valve core 624 away from the first valve core 623 through an L-shaped linkage rod 627 that can axially slide through the second valve sleeve 622, so that the annular compartment defined by the valve housing tube 61, the first valve core 623, the second valve core 624 and the elastic diaphragm 625 can form a bypass diversion sub-chamber structure linked to the second valve core 624 together with the annular reinforcement push block 626 and the L-shaped linkage rod 627, that is, the reinforcement liquid flow supply action of the bypass diversion sub-chamber structure is associated with the movement of the second valve core 624, and the bypass flow channel formed by the bypass diversion sub-chamber structure is parallel to the diversion channel. Specifically, the annular reinforcement push block 626 can move synchronously with the second valve core 624 under the pull 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 is variably conductive, the annular reinforcement push block 626 can synchronously change the volume of the annular cavity and the shape of the elastic diaphragm 625, thereby achieving follow-up reinforcement of the single pulse flow fluctuation generated when the diversion channel is conductive, thereby improving the intensity of the liquid flow pulse. Preferably, the second valve core 624 is also sleeved with a first elastic member 628 that defines its initial insertion position in the second valve sleeve 622. Preferably, sealing gaskets 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 gaps, ensuring relative mobility between the two while preventing overflow of liquid.

[0039] Preferably, a plurality of diversion through-ports 6211 corresponding one-to-one with the first through-ports 611 are defined on the sidewall of the first valve sleeve 621. Preferably, a receiving step 6212 capable of accommodating the annular reinforcement push block 626 is defined on the side of the first valve sleeve 621 adjacent to the second valve sleeve 622. Specifically, the receiving step 6212 of the first valve sleeve 621 cooperates with the inner wall of the valve housing 61 to form an annular receiving groove for accommodating the annular reinforcement push block 626. Preferably, a sealing gasket is provided on the side of the diversion through-ports 6211 to fill the assembly gap between the first valve sleeve 621 and the first valve core 623, thereby preventing drilling fluid from flowing into the assembly gap between the first valve sleeve 621 and the first valve core 623.

[0040] Preferably, a narrow step 6221 is provided within the through-hole cavity of the second valve sleeve 622, into which the second valve core 624 is inserted. The narrow step 6221 cooperates with the second valve core 624 to define the operating position of the first elastic member 628. Preferably, a sealing gasket is also provided on the inner wall of the through-hole cavity of the second valve sleeve 622 to fill the gap. Preferably, the second valve sleeve 622 is provided with a first through-hole 6222 that communicates with the annular compartment and is capable of outputting the reinforced drilling fluid flow within the annular compartment, and a second through-hole 6223 that movably receives the L-shaped linkage rod 627.

[0041] like Figure 4 and Figure 6As shown, a first transverse through hole 6232, a second transverse through hole 6233, and a third transverse through hole 6234 are provided on the sidewall surface of the first valve core body 6231 of the first valve core 623, and the through holes have successively increasing cross-sections for inputting drilling fluid. Specifically, the first transverse through hole 6232, the second transverse through hole 6233, and the third transverse through hole 6234 are arranged in an annularly spaced manner in a staggered distribution within the same annular surface. That is, the three through hole structures of different sizes defined by the first transverse through hole 6232, the second transverse through hole 6233, and the third transverse through hole 6234 are evenly spaced on the same annular sidewall, so that each of the three through holes is adjacent to each other. Preferably, the first transverse through hole 6232, the second transverse through hole 6233, and the third transverse through hole 6234 are strip-shaped cavity channels with gradually increasing diversion cross-sections. Specifically, the first transverse through hole 6232, the second transverse through hole 6233, and the third transverse through hole 6234 have equal widths, and the ratio of their lengths is 1:2:3. This allows different flow rates to pass through them, allowing different through hole structures to generate fluid flow fluctuations of varying intensities when they are connected. These fluid flow fluctuations are then used to form fluid flow pulses of varying intensities. These fluid flow pulses with varying peak values ​​can be used in conjunction with each other for communication programming, enabling more accurate and efficient data transmission with fewer pulse fluctuations. Preferably, a first central vertical through hole 6235 is centrally located on the end surface of the first valve core body 6231 facing the second valve core 624, capable of simultaneously communicating with the first transverse through hole 6232, the second transverse through hole 6233, and the third transverse through hole 6234 and outputting drilling fluid. Preferably, a one-way valve capable of limiting the flow of fluid in one direction is provided in the first central vertical through hole 6235. Specifically, the one-way valve restricts liquid flow to only flow from the first transverse through hole 6232, the second transverse through hole 6233, or the third transverse through hole 6234 into the first central vertical through hole 6235. Preferably, the end of the first valve core body 6231 away from the second valve core 624 is connected to a transmission assembly 65 that can drive it to rotate around its axis.

[0042] like Figure 5As shown, a second central vertical through hole 6243 for inputting drilling fluid is defined on the end surface of the second valve body 6241 of the second valve core 624, facing the first valve body 6231. Furthermore, preferably, a plurality of fourth transverse through holes 6242 are defined on the side of the second valve body 6241 in a rotationally symmetrical pattern, communicating with the second central vertical through hole 6243 and outputting drilling fluid. Preferably, the fourth transverse through holes 6242 have an elongated cavity cross-section, enabling them to change the cross-sectional size of the cavity they actually conduct as the second valve body 6241 rises and falls. This allows them to adjustably communicate with the cavity of the valve housing 61 below the second valve sleeve 622, forming diversion channels of varying sizes. This allows the size of the pulsed fluid output to vary, thereby generating pulsed fluid fluctuations of varying amplitudes. Preferably, a first elastic member 628 is sheathed around the outer surface of the second valve body 6241, which defines its initial operating position when inserted into the second valve sleeve 622. Preferably, a one-way valve is also provided in the second central vertical through hole 6243 to restrict the flow of liquid in one direction, so that liquid can only flow from the second central vertical through hole 6243 to the fourth transverse through hole 6242. Preferably, sealing gaskets are provided above and below the fourth transverse through hole 6242 to prevent drilling mud from intruding into the space where the first elastic member 628 is housed, thereby ensuring the stability and effectiveness of the elastic expansion and contraction of the first elastic member 628 and preventing mud from adhering to it and preventing effective expansion and contraction. Preferably, the axial lower end of the second valve core body 6241, which is away from the first valve core body 6231, is also connected to the L-shaped linkage rod 627, ensuring the synchronous movement of the L-shaped linkage rod 627.

[0043] Specifically, during actual operation, the selective opening of the first transverse through hole 6232, the second transverse through hole 6233, or the third transverse through hole 6234 results in differences in the flow rate within the diversion channel and the downward pressure exerted on the second valve core body 6241. Consequently, the second valve core body 6241 experiences different degrees of downward movement at different speeds, and the limit support spring represented by the first elastic member 628 also experiences equal compression at the same compression deformation speed. Simultaneously, the annular reinforcement push block 626 is also synchronously pulled to produce equivalent movement. For example, when the first transverse through hole 6232 is open, the instantaneous hydraulic pressure increase in the diversion channel is small, the second valve core body 6241 experiences a slight downward movement, and, limited by the elasticity of the first elastic member 628, its downward movement speed is also slow. The equivalent movement and speed of the annular reinforcement push block 626 are small, and the replenishment amount is moderate, which to some extent enhances the output fluctuation of the actual pulsed liquid flow.

[0044] 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.

[0045] 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.

[0046] 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 6243 and the fourth transverse through-hole 6242 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 to form 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.

[0047] Preferably, when the first valve core body 6231 rotates under the drive of the driving unit 66, the settings of its rotation period, intermittent frequency, speed, and movement direction will cause the intensity and peak value of a single pulse fluctuation and the number and frequency of pulse fluctuations in a single cycle to change, thereby being able to controllably generate a variety of different pulse signals and realize the effective transmission of different data. Specifically, the three intermittently conductive diversion channels defined by a single rotation of the first valve core body 6231 correspond to single signal carriers of 01, 02, and 03; when two consecutive intermittently conductive 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. The signal carriers can also be three-arrangement or four-arrangement, etc., and in the process of the above-mentioned fluctuations, the combination of modulation communication can be increased by limiting different gap periods, so as to characterize more well inclination 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.

[0048] Preferably, both the inner and outer annular surfaces of the annular reinforcing push block 626 are provided with sliding filler washers to ensure effective contact between the annular reinforcing push block 626 and the elastic diaphragm 625. The downwardly moving annular reinforcing push block 626, in a manner that forms a piston body, pushes the liquid in the annular body compartment to be effectively discharged from the first through-axis hole 6222. 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, which is driven by the increased hydraulic pressure in the diversion channel and undergoes radial outward expansion and deformation, is restrained by the annular reinforcing push block 626 and radially contracts inward. The volume of the segment chamber defined by the elastic diaphragm 625 is reduced, forcing the liquid flow in the segment chamber to be discharged under a higher hydraulic pressure state, further improving the pulse intensity and peak value. Preferably, the elastic diaphragm 625 is in the form of a frustum 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, so that the annular reinforcement push block 626 moving toward the second valve sleeve 622 can effectively scrape and compress the elastic diaphragm 625, so that the elastic diaphragm 625 can be more effectively constrained inward by the descending annular reinforcement push block 626, thereby improving the pressurization effect and strength of the section chamber defined by it.

[0049] Preferably, the sealing connection assembly 63 includes a sealing connection tube 631, a rotating sleeve 632, and a limit bearing 633. Preferably, the ends of the sealing connection tube 631 are connected to the valve housing tube 61 and the mounting sleeve 64, respectively, and the rotating sleeve 632 is inserted into the sealing connection tube 631. Preferably, a limit bearing 633 is sleeved on the rotating sleeve 632 to define a coaxial plug-in connection between the sealing connection tube 631 and the rotating sleeve 632, allowing for relative rotation. Specifically, the inner ring of the limit bearing 633 is fixedly connected to the outer ring of the rotating sleeve 632, and the outer ring of the limit bearing 633 is fixedly connected to the inner ring of the sealing connection tube 631. Further preferably, multiple sets of sealing gaskets are provided between the inner wall of the sealing connection tube 631 and the outer wall of the rotating sleeve 632 to fill the assembly gap and prevent drilling fluids such as mud from overflowing into the assembly gap. Further preferably, a plurality of sealing gaskets are embedded on the inner wall of the rotating sleeve 632 to fill the assembly gap between the rotating sleeve 632 and the transmission shaft 651 to prevent the drilling fluid from invading the driving unit 66 .

[0050] Preferably, the transmission assembly 65 includes a transmission shaft 651, a reducer 652, and a coupling 653. Preferably, the transmission shaft 651 is inserted into the rotating sleeve 632. The reducer 652 is connected to the axial upper end of the transmission shaft 651. Further preferably, the reducer 652 is transmission-connected to the coupling 653 at the axial upper end away from the transmission shaft 651. Specifically, the transmission shaft 651 and the output shaft of the reducer 652 are transmission-assembled by a sleeve connection. Specifically, the reducer 652 can be a reduction transmission structure with a large reduction ratio. For example, its reduction ratio can be 1:600. The rotation of the servo motor can actually be output as a small deflection of the transmission shaft 651, which facilitates the construction of different conductive flow channels according to needs and forms pulse fluctuations of different intensities. The pulse signal is formed by combining multiple different pulse fluctuations, shortening the total number of pulse fluctuations and the length of the fluctuation cycle, and realizing the efficient characterization of detection data using a combination of short multi-band pulse fluctuations. Specifically, coupling 653 is connected to the input shaft of reducer 652 using a keyed or tight fit, and a locking washer is installed to prevent the bolts from loosening. Preferably, coupling 653 is an elastic coupling that effectively transmits torque and prevents damage to the transmission structure caused by transient or short-term anomalies such as transmission jams.

[0051] Preferably, drive unit 66 is a servo motor capable of continuous forward rotation with adjustable speed or staggered forward and reverse rotation with adjustable single rotation amount, as required. Preferably, the output shaft of drive unit 66 is in driving connection with coupling 653, and the terminal of drive unit 66 is connected to the drive circuit unit corresponding to control unit 67. Preferably, control unit 67 is a drive circuit unit composed of a motor control circuit and a power supply circuit board, etc., which can control and set operating parameters of the servo motor represented by drive unit 66, limiting the servo motor's rotation direction, speed, rotation time, and interval time, etc. Specifically, drive unit 66 and control unit 67 are also connected to while-drilling detection module 4 via an internal cable passing through the stabilizer 2 and the flexible articulated joint 5 to achieve power supply and communication. Preferably, power supply unit 43 is connected to drive unit 66 and control unit 67 via a cable to supply power to both. Preferably, the inclinometer while drilling 41 and the gyro detection unit 42 are connected to the control unit 67 via a communication cable. The control unit 67 can generate pulse instructions consistent with the actual drilling parameters based on the data collected by the inclinometer while drilling 41 and the gyro detection unit 42, and then use the drilling fluid flow returned to the ground to effectively transmit the underground drilling data.

[0052] Preferably, the control unit 67 includes a connector and a circuit board. The connector is used to connect the while-drilling inclinometer 41 and the gyroscopic detection unit 42. The circuit board is installed with software that performs calculations and analysis on the data collected by the while-drilling inclinometer 41 and the gyroscopic detection unit 42. It also compares and verifies the well inclination parameters collected by the two independently acquired units, thereby supplementing missing data and correcting distorted data, generating well inclination data that best reflects actual drilling conditions, and improving the quality and accuracy of the data output by pulse communication. Preferably, the control unit 67 can output control instructions based on the processed well inclination data to modulate the motion parameters of the drive unit 66. Specifically, the adjustment of motion parameters means that the control unit 67 can set the rotation speed, rotation amount and rotation direction of the drive 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 drive unit 66, so that the drive unit 66 can continuously and directionally perform variable frequency rotation and / or alternating positive and negative quantitative deflection, so that the first transverse through hole 6232, the second transverse through hole 6233 and the third transverse through hole 6234 are selectively turned on, and the order of conduction and the duration of the conduction interval can be limited according to needs, so that the liquid flow fluctuations formed by intermittent conduction can generate pulse signals corresponding to the well inclination data.

[0053] Preferably, the present application also provides a method for measuring inclination while drilling using multi-band pulse communication, which comprises the following steps:

[0054] 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;

[0055] 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.

[0056] 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;

[0057] 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.

[0058] 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 multi-band pulse communication while drilling inclination measurement device, comprising a shell tube (3) connected to a fishing head (1) through a centralizer (2), characterized in that: A detection-while-drilling module (4) capable of monitoring real-time parameters of drilling is provided in the outer shell tube (3). The end of the shell tube (3) away from the fishing head (1) is connected to a pulse generating module (6) capable of outputting a pulse signal based on the real-time detection data obtained by the drilling detection module (4) through a series-connected centralizer (2) and a flexible hinged joint (5). The valve head assembly (62) of the pulse generating module (6) is capable of forming a flow guide channel with an adjustable flow cross section and intermittent opening and closing in the valve housing barrel (61) to form a pulsed liquid flow with variable intensity, and the valve head assembly (62) is also capable of cooperating with the valve housing barrel (61) to form a bypass diversion sub-cavity structure for supplying a supplementary liquid flow in association with the real-time conduction state of the diversion channel; The first valve sleeve (621) and the second valve sleeve (622) of the valve head assembly (62) are inserted into the valve housing (61) at intervals, and a first valve core (623) and a second valve core (624) are movably inserted into the valve body cavities of the first valve sleeve (621) and the second valve sleeve (622), respectively. An elastic diaphragm (625) is provided between the first valve sleeve (621) and the second valve sleeve (622), which can cooperate with the valve housing cylinder (61) to form an annular cavity, and an annular reinforcing push block (626) capable of axial movement is also provided in the annular cavity. The annular reinforcing push block (626) is connected to the second valve core (624) via an L-shaped linkage rod (627) that passes through the second valve sleeve (622); A second central vertical through hole (6243) 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 (6242) communicating with the second central vertical through hole (6243) are provided on the side surface of the second valve core body (6241) in a rotationally symmetrical manner. 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).

2. The multi-band pulse communication while drilling inclination measurement device according to claim 1, characterized in that: The valve housing (61) is connected to the mounting sleeve (64) via a sealing connection assembly (63), and a valve head assembly (62) capable of relative position change is inserted into the valve housing (61). The valve head assembly (62) is connected to a drive unit (66) installed in the mounting sleeve (64) via a transmission assembly (65) that moves through the sealing connection assembly (63), and a control unit (67) for setting motion parameters of the drive unit (66) is also provided in the mounting sleeve (64).

3. The multi-band pulse communication while drilling inclination measurement device according to claim 2, characterized in that: A first transverse through hole (6232), a second transverse through hole (6233) and a third transverse through hole (6234) are provided on the side wall surface of the first valve core body (6231) of the first valve core (623); A first central vertical through hole (6235) capable of communicating with the first transverse through hole (6232), the second transverse through hole (6233) and the third transverse through hole (6234) is provided on the end surface of the first valve core body (6231) facing the second valve core (624).

4. The multi-band pulse communication while drilling inclination measurement device according to claim 3, characterized in that: 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).

5. The multi-band pulse communication while drilling inclination measurement device according to claim 4, 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).

6. A method for measuring inclination while drilling with multi-band pulse communication, comprising the device for measuring inclination while drilling with multi-band pulse communication according to claim 5, 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.

7. The method for measuring inclination while drilling using multi-band pulse communication according to claim 6, wherein: 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.

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