Underground multi-source compatible measurement-while-drilling system based on grafting technology

Abstract

The invention discloses an underground multi-source compatible measurement-while-drilling system based on the grafting technology, and relates to the field of oil well drilling, the system comprises an oil well drilling device and a ground decoder, the oil well drilling device comprises a shear valve type mud pulse generator, a pulse righting module, a grafting conversion connector and a directional exploring tube which are sequentially connected in series; the directional exploring tube is used for collecting well drilling sensing parameters through the sensor module; the grafting adapter is used for transmitting well drilling sensing parameters to the shear valve type mud pulse generator; the pulse centralizing module comprises a centralizer and a shock absorber, and the shock absorber is used for executing self-adaptive shock absorption operation according to the vibration information of the oil well drilling device; the shear valve type mud pulse generator is used for generating a mud pressure pulse sequence according to the drilling sensing parameters; and the ground decoder is used for decoding the mud pressure pulse sequence to obtain corresponding drilling measurement parameters. Therefore, compatibility and synchronous transmission of the multi-source sensing signals are realized, and the transmission reliability of the mud pulse signals is guaranteed.

Description

Technical Field

[0001] The present application relates to the technical field of oil well drilling, and in particular to a downhole multi-source compatible measurement while drilling system based on grafting technology. Background Art

[0002] In the process of oil and gas exploration, downhole measurement while drilling (LWD) technology plays a vital role. It can obtain real-time data information of various physical quantities downhole, such as temperature, pressure, vibration, etc.

[0003] Traditional downhole pulsers rely on the dynamic characteristics of mud fluid to transmit pulse signals. However, when working in mud, factors such as mud composition, rheology, and water content will directly affect the transmission effect of pulse signals. For example, high-viscosity substances or particles in the mud will change the fluidity of the mud, thereby affecting the generation and propagation of pulses and the accuracy of downhole measurement data. In particular, as the depth of the well increases, ultra-deep well operations usually require the use of plugging agents containing high-viscosity substances or particles to solve the problem of well fluid leakage, but these plugging agents may hinder the normal propagation of pulse signals, resulting in signal loss, attenuation, or severe distortion.

[0004] In addition, in modern oil and gas exploration, downhole measurements usually require the simultaneous acquisition of signals from multiple sensors (such as well inclination, pressure, temperature, vibration, etc.). The working principle of the downhole pulser can only transmit periodic pulse signals, but there are great limitations for the transmission of multi-source sensor signals. Different sensors may output different types of data (such as continuous data, discrete data, etc.), and the downhole pulser cannot effectively be compatible with and synchronously transmit multi-source sensor signals.

[0005] In response to the above problems, the industry has not yet proposed a better technical solution. Summary of the invention

[0006] The present application provides a downhole multi-source compatible measurement while drilling system based on grafting technology, which is used to at least solve the problems of unstable downhole signal transmission, insufficient measurement accuracy or incompatibility of multi-source signals existing in traditional technologies.

[0007] An embodiment of the present application provides a downhole multi-source compatible measurement while drilling system based on grafting technology, including an oil well driller and a ground decoder, wherein the oil well driller comprises a shear valve mud pulse generator, a pulse straightening module, a grafting conversion joint and a directional probe connected in series; the directional probe is used to collect drilling sensor parameters through a sensor module; the drilling sensor parameters include at least one of the following parameter types: well inclination, azimuth, formation temperature, oil well driller vibration information and downhole pressure; the grafting conversion joint is used to transmit the drilling sensor parameters to the shear valve mud pulse generator; the pulse straightening module comprises a straightener and a shock absorber, and the shock absorber is used to perform adaptive shock absorption operations according to the vibration information of the oil well driller; the shear valve mud pulse generator is used to generate a mud pressure pulse sequence according to the drilling sensor parameters; the ground decoder is used to decode the mud pressure pulse sequence to obtain corresponding drilling measurement parameters.

[0008] The downhole multi-source compatible measurement while drilling system based on grafting technology provided by the present application can produce at least the following technical effects: (1) By adopting a shear valve mud pulse generator to replace the traditional sitting key pulser, the pulse signal is generated through mechanical shearing action, which reduces the dependence on the fluid dynamics of the mud, thereby ensuring stable signal transmission in the environment of high viscosity mud or plugging agent containing particulate matter.

[0009] (2) By grafting the conversion joint, different types of drilling sensor parameters (such as well inclination, azimuth, formation temperature, vibration information, downhole pressure, etc.) can be effectively transmitted to the shear valve mud pulse generator, supporting compatible transmission of multi-source sensor signals. In addition, the shear valve mud pulse generator can generate corresponding mud pressure pulse sequences based on multi-source sensor parameters, thereby ensuring the accurate acquisition and synchronous analysis of multiple measurement data, meeting the needs of parallel processing of multi-source signals in modern oil and gas exploration.

[0010] (3) The shock absorber set in the pulse straightening module can perform adaptive shock absorption operations according to the vibration information of the oil well driller, dynamically offset vibration interference, ensure the integrity of the pulse signal, effectively reduce the interference of vibration or high-viscosity materials on the pulse signal, ensure the stability of the pulse signal under complex working conditions, and improve the transmission accuracy of downhole measurement data. Therefore, even in ultra-deep well operations and under conditions of poor mud rheology, signal loss and attenuation can be greatly reduced, significantly improving the reliability of measurement data during exploration.

[0011] Through this technical solution, the grafting technology, adaptive shock absorption technology and shear valve mud pulse generator are comprehensively applied to achieve the compatibility and synchronous transmission of multi-source sensor signals, and ensure the reliability of mud pulse signal transmission, optimize the adaptability and work efficiency of the downhole measurement system under complex working conditions, and significantly improve the reliability and accuracy of downhole measurement data during oil and gas exploration. BRIEF DESCRIPTION OF THE DRAWINGS

[0012] In order to more clearly illustrate the embodiments of the present application or the technical solutions in the prior art, a brief introduction will be given below to the drawings required for use in the embodiments or the description of the prior art. Obviously, the drawings described below are some embodiments of the present application. For ordinary technicians in this field, other drawings can be obtained based on these drawings without paying any creative work.

[0013] Figure 1 A schematic structural diagram of an example of a downhole multi-source compatible measurement while drilling system based on a grafting technology according to an embodiment of the present application is shown; Figure 2 A schematic structural diagram of an example of an oil well drilling device according to an embodiment of the present application is shown; Figure 3 An operation flow chart showing an example of determining a damping adjustment weight and a stiffness adjustment weight by a sample learning method according to an embodiment of the present application; Figure 4 An operational flow chart showing an example of a shear valve mud pulse generator generating a mud pressure pulse sequence according to drilling sensor parameters according to an embodiment of the present application. DETAILED DESCRIPTION

[0014] In order to make the purpose, technical solution and advantages of the embodiments of the present application clearer, the technical solution in the embodiments of the present application will be clearly and completely described below in conjunction with the drawings in the embodiments of the present application. Obviously, the described embodiments are part of the embodiments of the present application, not all of the embodiments. Based on the embodiments in the present application, all other embodiments obtained by ordinary technicians in this field without creative work are within the scope of protection of this application.

[0015] It should be noted that in the current related technologies, the shear valve mud pulse generator adopts a shear valve design, which drives the rotor to shear the mud to generate mud pressure pulses through a motor, making it less likely to be blocked in the mud. Taking the rotary pulse generator launched by APS Technology as an example, it can provide more stable signal transmission and stronger adaptability when facing plugging agents and other mud components.

[0016] However, although the shear valve mud pulse generator has good mud adaptability, its performance in directional exploration applications is not ideal. In the process of practicing this application, the inventor of the present application found that the shear valve mud pulse generator has poor working stability, especially under complex geological conditions, its seismic resistance is weak, and when the drill has a large amplitude, its working signal will be unstable, resulting in poor accuracy of downhole measurement data.

[0017] It should be understood that the purpose of the above description of the current related art is only to facilitate the public to better understand the inventive spirit and motivation of the present application, and is not to be regarded as a limitation of the present application. In addition, the technical solutions described in the above-mentioned current related art are not prior art, and may also be undisclosed technical solutions, such as solutions under research or in the laboratory stage.

[0018] Figure 1 A schematic structural diagram of an example of a downhole multi-source compatible measurement while drilling system based on grafting technology according to an embodiment of the present application is shown.

[0019] like Figure 1 As shown, a downhole multi-source compatible measurement while drilling system 100 based on the grafting technology includes an oil well driller 110 and a surface decoder 120 .

[0020] The oil well drilling device 110 comprises a shear valve type mud pulse generator 111, a pulse straightening module 112, a grafting conversion joint 113 and a directional probe 114 which are sequentially connected in series.

[0021] The directional probe 114 is used to collect drilling sensor parameters through the sensor module. The drilling sensor parameters include at least one of the following parameter types: well inclination angle, azimuth angle, formation temperature, oil well driller vibration information and downhole pressure.

[0022] Specifically, directional probes are high-precision detection equipment used in oil and gas exploration. The instrument types can be diverse, such as Tolteq, KeyDrill, GE probes, etc. They have high working stability, accuracy and temperature resistance, and can provide more accurate formation information in the underground working environment to ensure measurement accuracy.

[0023] In addition, the sensor module can use high-precision sensors (such as MEMS accelerometers, temperature sensors, pressure sensors, etc.) to perform downhole measurements, and different types of sensing parameters can be set with corresponding sampling frequencies to ensure the accuracy of sensing measurements. Therefore, the combination of directional probes and sensor modules enables downhole multi-source data to be accurately collected in real time.

[0024] The grafting conversion joint 113 is used to transmit the drilling sensor parameters to the shear valve type mud pulse generator 111.

[0025] Here, the grafting conversion joint provides an interface for each sensor, so that the sensor signal can be transmitted to the grafting conversion joint. In addition, multiplexing technology (such as time division multiplexing TDM or frequency division multiplexing FDM) can be used to merge multiple source signals into a single data stream and relay it to the shear valve mud pulse generator to achieve efficient fusion and transmission of multi-source sensor signals.

[0026] The impulse straightening module 112 comprises a straightening device 1121 and a shock absorber 1123. The shock absorber 1123 is used to perform an adaptive shock absorption operation according to the vibration information of the oil well driller.

[0027] Specifically, the main function of the centralizer 1121 is to ensure the stability and directionality of the pulse generator and prevent the pulse signal from deviating from the predetermined path due to mud flow or vibration in the well. The shock absorber 1123 can be adjusted in real time based on the vibration information of the driller, and adopts advanced adaptive shock absorption technology to automatically adjust the shock absorption strength according to the real-time vibration data to minimize the interference of vibration on the pulse signal.

[0028] In particular, as described above, the shear valve mud pulse generator has weak anti-vibration performance. When the drill has a large amplitude, the vibration noise signal will destroy the integrity of the mud pulse, resulting in poor accuracy of downhole measurement data.

[0029] By setting the shock absorber in the pulse straightening module, it is possible to perform adaptive shock absorption operations according to the vibration information of the oil well driller, dynamically offset vibration interference, ensure the integrity of the pulse signal, effectively reduce the interference of vibration or high-viscosity materials on the pulse signal, ensure the stability of the pulse signal under complex working conditions, and improve the transmission accuracy of downhole measurement data. Therefore, even in ultra-deep well operations and when the mud rheology is poor, the loss and attenuation of the signal can be greatly reduced, significantly improving the reliability of the measurement data during the exploration process. Through real-time shock absorption control, the accuracy of downhole measurement data is ensured and the attenuation or distortion of the signal is avoided.

[0030] The shear valve mud pulse generator 111 is used to generate a mud pressure pulse sequence according to drilling sensor parameters.

[0031] Here, a shear valve mud pulse generator is used to replace the traditional sitting key pulser, and a pulse signal is generated through mechanical shearing action, which reduces the dependence on the fluid dynamics of the mud, thereby ensuring stable signal transmission in high-viscosity mud or plugging agent environments containing particulate matter.

[0032] Specifically, after receiving the multi-source drilling sensor parameters transmitted by the grafting conversion joint, the shear valve mud pulse generator drives the rotor to shear the mud to produce pressure pulses through the motor, and generates a corresponding mud pressure pulse sequence according to the multi-source sensor signals transmitted by the grafting conversion joint, thereby ensuring the accurate acquisition and synchronous analysis of multiple measurement data, and meeting the needs of parallel processing of multi-source signals in modern oil and gas exploration.

[0033] The surface decoder 120 is used to decode the mud pressure pulse sequence to obtain corresponding drilling measurement parameters.

[0034] Here, the ground decoder can restore the drilling measurement parameters through the decoding algorithm, for example, by using pulse frequency analysis, amplitude modulation decoding and other technologies to extract various physical quantities downhole from complex pulse signals. In addition, adaptive filtering technology can be used to eliminate noise interference in the mud environment and improve decoding accuracy.

[0035] Through the embodiment of the present application, the shear valve mud pulse generator is combined with the pulse straightening module, the grafting conversion joint and the directional probe design, which can work stably under complex well conditions and ensure the synchronous transmission and high-precision decoding of multi-source signals. As a result, the data acquisition accuracy, real-time and reliability in the oil and gas exploration process have been significantly improved, especially under complex geological conditions, the seismic resistance and adaptability of the system have been enhanced, providing stronger technical support for oil and gas exploration.

[0036] Figure 2 A schematic structural diagram of an example of an oil well drill according to an embodiment of the present application is shown.

[0037] like Figure 2 As shown, the oil well drilling device 110 is also provided with a tail cone 115 and a battery module 116 .

[0038] Specifically, the tail cone 115 is a sealing joint that matches the directional probe 114 and is used to straighten the directional probe 114. For example, the tail cone 115 can be made of high-strength materials (such as titanium alloy or high-strength steel) to ensure its durability in the complex environment of the well, and a sealing structure is designed inside to prevent mud or other impurities from invading. In addition, the tail cone 115 dynamically straightens the directional probe 114 through a mechanical structure (such as a spring or a hydraulic device) to ensure that it remains stable during the drilling process. Its straightening function can effectively reduce the shaking of the directional probe 114 during the drilling process.

[0039] The battery module 116 is connected in series between the pulse straightening module 112 and the grafting conversion joint 113. The battery module 116 includes a plurality of power supply units (not shown) connected in series, and each power supply unit includes a battery and a battery straightener to provide a stable power supply for the system.

[0040] Here, the battery can be a high-energy-density lithium battery or a high-temperature-resistant battery to ensure stable operation in the high-temperature and high-pressure environment underground. In addition, the battery stabilizer can dynamically stabilize the battery through a mechanical structure (such as a spring or hydraulic device) to prevent the battery from being damaged by vibration during drilling. In some cases, each power supply unit can also be designed as a main and backup power supply mode. When the main battery is detected to be low in power or a battery failure, it can automatically switch to the backup power supply unit to provide power supply to ensure the continuity of power supply.

[0041] Regarding the details of the adaptive shock absorption operation, the working state of the shock absorption system is adjusted in real time according to the vibration signal of the drilling tool. Specifically, through the monitored vibration information (vibration frequency and amplitude), the parameters of the shock absorber will be dynamically adjusted to achieve adaptive shock absorption and reduce the interference of the vibration of the drilling tool on the mud pulse generator and the downhole measurement system.

[0042] In some embodiments, the vibration frequency and amplitude are extracted from the time domain signal of the oil well driller vibration information, and the damping coefficient or stiffness coefficient of the shock absorber is adjusted in real time according to the extracted vibration frequency and amplitude: , Formula (1) , Formula (2) In the formula, It's time The damping coefficient, is the basic damping coefficient, is the damping adjustment weight, It's time Amplitude of It's time The stiffness coefficient, is the foundation stiffness coefficient, is the stiffness adjustment weight, It's time The vibration frequency.

[0043] In the embodiment of the present application, the vibration information of the downhole tool is monitored and fed back to the shock absorber system. or vibration frequency When changes occur, the system calculates the new shock absorber parameters (i.e., damping coefficient and stiffness coefficient ), and then adjust the working state of the shock absorber, so that the shock absorber can adaptively adjust its shock absorption performance according to different drilling operation conditions (such as different depths, formation properties, drilling methods, etc.), and can effectively cope with complex and changeable geological conditions and downhole vibrations.

[0044] In combination with business scenarios, during the operation of the oil well driller, when the vibration frequency is high (for example, in hard formations or during rapid drilling), the system will increase the damping coefficient. , in order to reduce the vibration response of the system; when the vibration amplitude is large (for example, encountering softer strata or geologically complex areas), the stiffness coefficient is appropriately increased. , so as to prevent the shock absorber from being unable to provide sufficient support due to excessive shock absorption.

[0045] Through the embodiments of the present application, by adjusting the damping coefficient and stiffness coefficient of the shock absorber in real time, adaptive shock absorption can be performed for different vibration characteristics (such as vibration frequency and amplitude), thereby effectively improving the shock absorption effect of the system, ensuring the stability of the mud pulse signal, and maintaining high accuracy and reliability of downhole measurement data under various types of complex geological conditions.

[0046] Regarding the damping adjustment weights in the above equations (1) and (2): and stiffness adjustment weights The determination can be set by the user on the one hand, or determined by sample learning on the other hand, and both fall within the scope of implementation of the embodiments of the present application.

[0047] Figure 3 An operational flowchart of an example of determining a damping adjustment weight and a stiffness adjustment weight by a sample learning method according to an embodiment of the present application is shown.

[0048] like Figure 3 As shown, in step S310, a vibration pulse sample set is obtained, and a vibration reduction parameter tuning operation is performed for each vibration pulse sample in the vibration pulse sample set.

[0049] Here, during the drilling operation, the downhole sensor module will continuously collect the vibration signal of the driller, combine it with the mud pressure pulse acted by the shear valve mud pulse generator, and build a sample set together with the state parameters of the shock absorber to facilitate the optimization of the working state of the shock absorber.

[0050] In some embodiments, the input state is defined based on the vibration frequency, amplitude, shock absorber damping coefficient and shock absorber stiffness coefficient in the vibration pulse sample to determine the corresponding output action group through reinforcement learning, and each output action in the output action group is used to indicate the corresponding damping coefficient adjustment amplitude and stiffness coefficient adjustment amplitude respectively.

[0051] Here, for each vibration pulse sample, the system will perform a shock absorption parameter tuning operation to adjust the damping coefficient and stiffness coefficient of the shock absorber. The tuning process is based on reinforcement learning technology, and the parameters of the shock absorber are gradually optimized through a feedback mechanism to reduce the interference of vibration on equipment and signal transmission during drilling.

[0052] More specifically, the current environmental state of the shock absorption system is fully described by using the diversified parameter selection in the input state, providing sufficient conditional information for reinforcement learning. Then, the output action group is determined by reinforcement learning algorithms (such as Q-Learning or deep reinforcement learning), and the shock absorption parameters are dynamically optimized through interaction with the environment to adapt to complex vibration conditions, and a variety of potential adjustment schemes are provided through the output action group.

[0053] Furthermore, the pulse signals after applying each output action in the output action group are obtained, and the pulse signal distortion is calculated in combination with the initial pulse signal in the vibration pulse sample. The corresponding target damping coefficient adjustment amplitude and target stiffness coefficient adjustment amplitude are determined according to the target output action with the smallest corresponding pulse signal distortion in the output action group.

[0054] More specifically, for each output action in the output action group, a shock absorber with adjusted damping coefficient and stiffness coefficient is applied, and a corresponding pulse signal (such as a pulse signal received by a ground decoder) is collected, and the pulse signal is compared with an initial pulse signal (i.e., a mud pressure pulse signal recorded by a sample and acted upon by a shear valve mud pulse generator) to obtain a corresponding pulse signal distortion. Further, the signal distortions caused by different output actions are compared according to the distortions, and the output action with the smallest distortion is selected as the target output action.

[0055] For example, the target output action can be automatically adjusted through the reward mechanism in the reinforcement learning algorithm, for example, the reward function is designed to be a function negatively correlated with the distortion, so that the smaller the distortion, the greater the reward value. Therefore, through reinforcement learning, the optimal damping coefficient adjustment range and stiffness coefficient adjustment range under the environmental conditions indicated by the sample can be automatically selected.

[0056] In some examples of the embodiments of the present application, the calculation formula for the pulse signal distortion is: , Formula (3) In the formula, Indicates output action At the moment The corresponding pulse signal distortion, Indicates at time Apply output actions The pulse signal obtained is represents the distortion analysis time window, Indicates at time The initial pulse signal.

[0057] In formula (3), the pulse signal is calculated by integration and the initial pulse signal The difference between the two quantifies the degree of distortion. In addition, by using the squared error Measures signal differences, ensuring that distortion calculations are more sensitive to larger differences. Distortion Analysis Time Window It is the time range used to calculate the distortion, which can be set according to the period and vibration characteristics of the pulse signal and can be adjusted dynamically.

[0058] According to the above formula (3), the distortion Quantified application output actions Post pulse signal With the initial pulse signal The difference between , ensuring that the pulse signal after applying the output action is as close as possible to the initial pulse signal, thereby reducing signal distortion. The indicated damping coefficient adjustment range and stiffness coefficient adjustment range will affect the shock absorption effect and thus affect the pulse signal By calculating the distortion, the system can evaluate the pulse anti-distortion effect of different damping parameter adjustment schemes and select the optimal output action.

[0059] In step S320, the damping adjustment weight is calculated according to the current damping coefficient of the shock absorber in each vibration pulse sample and the corresponding target damping coefficient adjustment amplitude, and the stiffness adjustment weight is calculated according to the current stiffness coefficient of the shock absorber in each vibration pulse sample and the corresponding target stiffness coefficient adjustment amplitude.

[0060] Referring to the above formula (1) and formula (2), it can be known that the difference between the current shock absorber damping coefficient and the target damping coefficient is calculated for each sample in the vibration pulse sample set, and the difference determines the weight of the damping adjustment. The shock absorber parameter adjustment weight indicated by all samples in the vibration pulse sample set is statistically calculated, such as by averaging all samples, to obtain the final corresponding damping adjustment weight. and stiffness adjustment weights , which can reflect the adjustment trend of the damping coefficient and stiffness coefficient under different vibration conditions.

[0061] Through the embodiment of the present application, a sample learning method is adopted to adjust the parameters of the shock absorber in real time according to the vibration pulse samples actually collected, thereby improving the adaptability of the shock absorber to different downhole environments and drilling conditions. In addition, by comparing different output actions and distortions through reinforcement learning, the optimal shock absorption parameter adjustment strategy can be quickly found, greatly improving the dynamic response capability of the system. Therefore, the automatic tuning mechanism based on sample learning can respond to the ever-changing vibration characteristics during the drilling process in real time, reducing the need for human intervention.

[0062] In some examples of the embodiments of the present application, Damping adjustment weight and stiffness adjustment weights The calculation formula is: , Formula (4) , Formula (5) , Formula (6) In the formula, Representation sample At the moment The pulse signal distortion corresponding to the target output action, represents the feedback factor, Representation sample At the moment The target damping coefficient adjustment range is Representation sample At the moment The target stiffness coefficient adjustment range is Representation sample At the moment The amplitude of Representation sample At the moment The stiffness coefficient, Indicates the reference maximum distortion.

[0063] Here, the feedback factor According to the distortion The purpose is to dynamically modify the weight according to the distortion of each sample, reflecting the pulse distortion of the sample. In addition, when calculating the damping adjustment weight and stiffness adjustment weight, the feedback factor of each sample is Weighted, combined with its adjustment range or , and normalized according to the vibration amplitude or stiffness coefficient, which ensures that the influence of each sample is reasonably reflected in the final weight.

[0064] Through the embodiments of the present application, the working parameters of the shock absorber are dynamically adjusted according to the actual vibration pulse samples, which can effectively cope with the complex and changeable geological environment and vibration mode during drilling, and ensure that the shock absorber can be maintained in the optimal state. In addition, by calculating the feedback factor based on the pulse distortion, the system can effectively adjust the damping and stiffness, minimize vibration interference, and improve the shock absorption effect of the system; adjusting the parameters of the shock absorber based on the feedback of the pulse signal distortion can greatly reduce the distortion of the mud pulse signal and improve the accuracy and reliability of the downhole measurement data.

[0065] Figure 4An operational flow chart showing an example of a shear valve mud pulse generator generating a mud pressure pulse sequence according to drilling sensor parameters according to an embodiment of the present application.

[0066] like Figure 4 As shown, in step S410, for at least one sensing parameter value among the drilling sensing parameters, a corresponding encoding method is called according to the sensing parameter type of the sensing parameter value to encode the sensing parameter value to determine a corresponding encoding subframe, and a corresponding transmission time slot is configured for the encoding subframe according to the sensing parameter time slot relationship table and the sensing parameter type of the sensing parameter value.

[0067] In some embodiments, the data of various parameters in the drilling process are obtained through the downhole sensor module. These parameters may include well inclination, azimuth, temperature, pressure, vibration, etc. The type and value of each parameter are different. According to the type of sensing parameter (such as temperature, pressure, vibration, etc.), a suitable encoding method is selected. For example, temperature and pressure may be encoded using continuous values, while vibration and well inclination may be encoded using discrete values. Therefore, selecting a suitable encoding method for different types of drilling sensing parameters can compress data to the greatest extent and improve signal transmission efficiency.

[0068] In addition, a variety of sensing parameter types and transmission time slots of corresponding durations are pre-stored in the sensing parameter time slot relationship table, that is, a variety of associations between sensing parameter types and transmission time slot durations are recorded. Exemplarily, the transmission time of the mud pulse signal is divided into multiple time slots, and each time slot is allocated to different sensor data. For example, high-priority data (such as well inclination and azimuth) is allocated more time slots to ensure its real-time nature; low-priority data (such as temperature and pressure) is allocated fewer time slots, but the accuracy is improved through multiple transmissions. Thus, appropriate transmission time slots are allocated to the coding subframes of each sensing type, ensuring the reliable transmission of various types of sensing data and reducing errors in the transmission process.

[0069] In step S420, the various coding subframes are combined to determine a corresponding drilling sensing coding frame.

[0070] In some embodiments, these coding subframes are combined in a predetermined order, such as a preset sensing type arrangement order, to obtain corresponding drilling sensing coding frames, ensuring that various sensing parameters can be transmitted in a specified order.

[0071] In step S430, the drilling sensor coding frame is divided into a plurality of data segments, and each data segment is mapped to pulse position information based on a pulse position modulation method to generate a corresponding mud pressure pulse sequence.

[0072] It should be noted that there are various pulse modulation methods, such as pulse position modulation (PPM), pulse width modulation (PWM) and pulse amplitude modulation (PAM). In the embodiment of the present application, due to the complexity of the mud environment, PPM suitable for low-bandwidth environment is adopted, and it is insensitive to amplitude changes and has strong anti-interference ability. Specifically, the drilling sensor coding frame is divided into multiple data segments, each data segment contains a certain amount of sensor parameter data. Through this division, the transmission of data in the pulse signal can be made more efficient, and each data segment corresponds to a position of the pulse signal.

[0073] In some embodiments, when generating a pulse sequence in the mud, the position of each pulse is adjusted according to the content of the data segment, for example, a specific value of a data segment may correspond to a specific position in the pulse signal, or the time of occurrence of the pulse. Then, each data segment is sequentially mapped to the mud pressure pulse according to the pulse position modulation rule to form a complete mud pressure pulse sequence for transmission between the downhole equipment and the ground decoder.

[0074] Through the embodiment of the present application, a large amount of sensor data is compressed into a sequence of mud pressure pulses through pulse position modulation, which has stronger robustness against interference from factors such as downhole vibration and noise compared to other modulation methods (such as amplitude modulation). By changing the position of the pulse instead of the amplitude, data can be transmitted more stably, signal loss and distortion can be reduced, and stable propagation of mud pulse signals in the well can be ensured.

[0075] Regarding the segmentation operation details of the data segments of the drilling sensor coding frame, it should be noted that the traditional fixed frame segmentation method may cause some data segments to be too long or too short, affecting the transmission efficiency. In addition, in the mud environment, the propagation characteristics of the pulse signal may change over time, and the segmentation strategy needs to be dynamically adjusted.

[0076] In view of this, the embodiment of the present application proposes to dynamically adjust the data segment length according to the channel status to maximize the data transmission efficiency. Thus, according to the real-time changes of the mud channel, the segmentation strategy is dynamically adjusted to ensure the reliability of data transmission.

[0077] In some embodiments, first, the real-time distortion of the pulse signal and the real-time signal-to-noise ratio of the channel for the mud transmission channel are received from a ground decoder, and the data segment length used for data segment division is dynamically adjusted according to the received real-time distortion of the pulse signal and the real-time signal-to-noise ratio of the channel.

[0078] Here, the real-time distortion and real-time signal-to-noise ratio of the mud transmission channel are received from the ground decoder to provide real-time channel status information, which provides a basis for dynamic segmentation optimization and ensures that the segmentation strategy can adapt to the dynamic changes of the channel.

[0079] Then, the drilling sensor coding frame is divided into multiple data segments according to the data segment length.

[0080] Here, the drilling sensor coding frame is divided into multiple data segments according to the dynamically adjusted data segment length to ensure the optimization of the segmentation strategy, which can effectively improve the efficiency of data transmission, reduce the impact of too long or too short data segments on transmission efficiency, ensure the reliability of data transmission, and adapt to the dynamic changes of the mud channel.

[0081] Specifically, the calculation formula for the data segment length is: , Formula (7) , Formula (8) In the formula, is the basic segment length, is the dynamically adjusted data segment length, is the adjustment factor, It is the real-time transmission quality indicator of the channel. Indicates the real-time signal-to-noise ratio of the channel, Indicates the real-time distortion of the pulse signal.

[0082] Through the embodiments of the present application, real-time channel status information is received through a ground decoder, and the frame data segmentation strategy is dynamically adjusted to ensure the optimization of the segmentation strategy. For example, when the channel quality is poor, the segment length is increased to improve the transmission efficiency; when the channel quality is good, the segment length is reduced to increase the transmission speed, thereby reducing the distortion of the pulse signal in the mud channel and ensuring the reliability of data transmission.

[0083] In some examples of the embodiments of the present application, the pulse position modulation method is an adaptive pulse modulation method based on channel state feedback. In a dynamic drilling environment, different data values ​​are reflected by adjusting the position of the pulse.

[0084] More specifically, the pulse position corresponding to each data segment is determined by the following formula: , Formula (9) In the formula, Indicates m The data segment length of each data segment, Indicates the maximum limit of the data segment length. Indicates m The pulse position corresponding to each data segment, represents the pulse cycle length, Represents the channel state feedback adjustment coefficient.

[0085] Regarding the explanation of formula (9), the pulse cycle length Defines the time taken by each pulse signal. By adjusting the pulse period, the data transmission rate and the stability of the pulse signal can be controlled. For example, a shorter pulse period may represent high efficiency of data transmission, but it may also sacrifice data accuracy; a longer pulse period may improve data accuracy, but may lead to a decrease in transmission rate. In addition, the channel state feedback adjustment coefficient It reflects the adjustment amplitude of the pulse position according to the channel transmission status, which can be preset.

[0086] Here, the specific pulse position of each data segment is determined by considering the length of the data segment and the channel quality. Specifically, in the pulse position modulation process, the pulse position is associated with the data segment length. First, the relative pulse position of the data segment is determined by the ratio of the length of the data segment to the maximum data segment length, so as to ensure that the position of each data segment in the pulse sequence is proportional to its length. In addition, the quality of the channel directly affects the accuracy of the pulse position. If the channel quality is poor, the feedback adjustment coefficient and channel state feedback coefficient Increasing the pulse adjustment amplitude ensures that data can be transmitted correctly even in an unstable channel environment.

[0087] Through the embodiments of the present application, through real-time feedback adjustment of channel quality, the position of the pulse signal can be dynamically adjusted during the drilling process, and the complex noise and vibration interference in the downhole environment can be adaptively resisted. When the channel quality is poor, the adjustment amplitude is increased to ensure that the signal can be correctly transmitted; when the channel quality is good, the adjustment amplitude is reduced, thereby improving the transmission efficiency. Therefore, the feedback mechanism based on the channel state ensures that data is not easily lost or bit errors occur during the signal transmission process, thereby improving the accuracy and reliability of downhole measurement data.

[0088] It should be noted that, for the aforementioned system embodiments, for the sake of simplicity of description, they are all expressed as a series of combined actions, but those skilled in the art should be aware that the present application is not limited by the order of actions described, because according to the present application, certain steps can be performed in other orders or simultaneously. Secondly, those skilled in the art should also be aware that the embodiments described in the specification are all preferred embodiments, and the actions and modules involved are not necessarily required by the present application. In the above embodiments, the description of each embodiment has its own emphasis. For parts that are not described in detail in a certain embodiment, please refer to the relevant description of other embodiments.

[0089] The system embodiment described above is merely illustrative, wherein the units described as separate components may or may not be physically separated, and the components shown as units may or may not be physical units, that is, they may be located in one place or distributed on multiple network units. Some or all of the modules may be selected according to actual needs to achieve the purpose of the solution of this embodiment.

[0090] Through the description of the above implementation methods, those skilled in the art can clearly understand that each implementation method can be implemented by means of software plus a general hardware platform, or of course by hardware. Based on this understanding, the above technical solution is essentially or the part that contributes to the relevant technology can be embodied in the form of a software product, and the computer software product can be stored in a computer-readable storage medium, such as ROM / RAM, a disk, an optical disk, etc., including a number of instructions for a computer device (which can be a personal computer, a server, or a network device, etc.) to execute the system described in each embodiment or some parts of the embodiment.

[0091] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present application, rather than to limit it. Although the present application has been described in detail with reference to the aforementioned embodiments, those skilled in the art should understand that they can still modify the technical solutions described in the aforementioned embodiments, or make equivalent replacements for some of the technical features therein. However, these modifications or replacements do not deviate the essence of the corresponding technical solutions from the spirit and scope of the technical solutions of the embodiments of the present application.

Claims

1. A downhole multi-source compatible measurement while drilling system based on grafting technology, comprising an oil well driller and a ground decoder, characterized in that: The oil well drilling device comprises a shear valve type mud pulse generator, a pulse righting module, a grafting conversion joint and a directional probe which are sequentially connected in series; The directional probe is used to collect drilling sensor parameters through the sensor module; the drilling sensor parameters include at least one of the following parameter types: well inclination angle, azimuth angle, formation temperature, oil well driller vibration information and downhole pressure; The grafting conversion joint is used to transmit the drilling sensor parameters to the shear valve type mud pulse generator; The impulse righting module comprises a righting device and a shock absorber, wherein the shock absorber is used to perform an adaptive shock absorption operation according to the vibration information of the oil well driller; The shear valve type mud pulse generator is used to generate a mud pressure pulse sequence according to the drilling sensor parameters; The ground decoder is used to decode the mud pressure pulse sequence to obtain corresponding drilling measurement parameters.

2. The system according to claim 1, characterized in that The shock absorber is used to perform an adaptive shock absorption operation according to the vibration information of the oil well driller, including: Extract the vibration frequency and amplitude from the time domain signal of the oil well driller vibration information, and adjust the damping coefficient or stiffness coefficient of the shock absorber in real time according to the extracted vibration frequency and amplitude: ， ， In the formula, It's time The damping coefficient, is the basic damping coefficient, is the damping adjustment weight, It's time Amplitude of It's time The stiffness coefficient, is the foundation stiffness coefficient, is the stiffness adjustment weight, It's time The vibration frequency.

3. The system according to claim 2, characterized in that The determination of the damping adjustment weight and the stiffness adjustment weight includes: Obtain a vibration pulse sample set, and perform a vibration reduction parameter tuning operation for each vibration pulse sample in the vibration pulse sample set: An input state is defined according to the vibration frequency, amplitude, shock absorber damping coefficient and shock absorber stiffness coefficient in the vibration pulse sample to determine a corresponding output action group through reinforcement learning; each output action in the output action group is used to indicate a corresponding damping coefficient adjustment amplitude and a stiffness coefficient adjustment amplitude respectively; Obtaining pulse signals after applying each of the output actions in the output action group, respectively, and calculating the pulse signal distortion in combination with the initial pulse signal in the vibration pulse sample, and determining the corresponding target damping coefficient adjustment amplitude and target stiffness coefficient adjustment amplitude according to the target output action in the output action group corresponding to the minimum pulse signal distortion; The damping adjustment weight is calculated according to the current damping coefficient of the shock absorber in each of the vibration pulse samples and the corresponding target damping coefficient adjustment range, and the stiffness adjustment weight is calculated according to the current stiffness coefficient of the shock absorber in each of the vibration pulse samples and the corresponding target stiffness coefficient adjustment range.

4. The system according to claim 3, characterized in that The calculation formula of pulse signal distortion is: ， In the formula, Indicates output action At the moment The corresponding pulse signal distortion, Indicates at time Apply output actions The pulse signal obtained is represents the distortion analysis time window, Indicates at time The initial pulse signal.

5. The system according to claim 4, characterized in that Damping adjustment weight and stiffness adjustment weights The calculation formula is: ， ， ， In the formula, Representation sample At the moment The pulse signal distortion corresponding to the target output action, represents the feedback factor, Representation sample At the moment The target damping coefficient adjustment range is Representation sample At the moment The target stiffness coefficient adjustment range is Representation sample At the moment The amplitude of Representation sample At the moment The stiffness coefficient, Indicates the reference maximum distortion.

6. The system according to claim 1, characterized in that The shear valve type mud pulse generator is used to generate a mud pressure pulse sequence according to the drilling sensor parameters, including: The shear valve mud pulse generator is used to perform the following operations: For at least one sensing parameter value of the drilling sensing parameters, a corresponding encoding method is called according to the sensing parameter type of the sensing parameter value to encode the sensing parameter value to determine a corresponding encoding subframe, and a corresponding transmission time slot is configured for the encoding subframe according to a sensing parameter time slot relationship table and the sensing parameter type of the sensing parameter value; the sensing parameter time slot relationship table pre-stores a plurality of sensing parameter types and transmission time slots of corresponding durations; Combining the respective coding subframes to determine a corresponding drilling sensing coding frame; The drilling sensor coding frame is divided into a plurality of data segments, and each data segment is mapped to pulse position information based on a pulse position modulation method to generate a corresponding mud pressure pulse sequence.

7. The system according to claim 6, characterized in that The step of dividing the drilling sensor coding frame into a plurality of data segments comprises: receiving a real-time distortion degree of a pulse signal and a real-time signal-to-noise ratio of a channel for a mud transmission channel from a ground decoder, and dynamically adjusting a data segment length for data segment division according to the received real-time distortion degree of the pulse signal and the real-time signal-to-noise ratio of the channel; Dividing the drilling sensor coding frame into a plurality of data segments according to the data segment length; The calculation formula of the data segment length is: ， ， In the formula, is the basic segment length, is the dynamically adjusted data segment length, is the adjustment factor, It is the real-time transmission quality indicator of the channel. Indicates the real-time signal-to-noise ratio of the channel, Indicates the real-time distortion of the pulse signal.

8. The system according to claim 7, characterized in that The pulse position modulation mode is an adaptive pulse modulation mode based on channel state feedback; The method of mapping each data segment into pulse position information based on the pulse position modulation method to generate a corresponding mud pressure pulse sequence includes: The pulse position corresponding to each data segment is determined by the following formula: ， In the formula, Indicates m The data segment length of each data segment, Indicates the maximum limit of the data segment length. Indicates m The pulse position corresponding to each data segment, represents the pulse cycle length, Represents the channel state feedback adjustment coefficient.

9. The system according to claim 1, characterized in that The system also includes a tail cone; the tail cone is a sealing joint matched with the directional probe and is used to straighten the directional probe.

10. The system according to claim 1, characterized in that The system also includes a battery module connected in series between the pulse straightening module and the grafting conversion joint, the battery module includes a plurality of power supply units connected in series, and each of the power supply units includes a battery and a battery straightener.

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