Method and system for optimizing underground drilling construction parameters of coal bed gas

Abstract

The invention relates to the technical field of automatic control of drilling parameters, in particular to a coal bed gas underground drilling construction parameter optimization method and system.The method comprises the following steps that sound wave response signals are obtained, propagation characteristics are calculated, bit pressure data are aligned, abnormal fluctuation is recognized, pumping pressure information is extracted, and the change trend is analyzed; and comparing the consistency of the regulation and control points and organizing regulation and control actions to finally form a coal-bed gas well drilling parameter optimization control flow. According to the method, accurate calibration of an abnormal state is achieved by constructing a sound wave propagation delay sequence and synchronizing bit pressure response, key regulation and control fragments are recognized in combination with a pumping pressure change trend, a time sequence coupling relation between bit pressure and pumping pressure is established, regulation and control action combinations meeting response consistency are extracted, and sequential organization is conducted; a control instruction set with continuity and pertinence is formed, collaborative recognition and linkage regulation and control of multi-parameter change trends are achieved, and stability and response coordination in the construction process are improved.

Description

Technical Field

[0001] This invention relates to the field of automatic control drilling parameters, and in particular to a method and system for optimizing drilling parameters in coalbed methane wells. Background Technology

[0002] The field of automatic drilling parameter control technology involves the real-time monitoring, dynamic analysis, and automatic adjustment of various parameters during drilling operations to improve drilling efficiency and construction safety. Core aspects of this technology include drill pressure control, rotation speed regulation, flushing fluid flow management, drill bit torque monitoring, wellbore deviation correction, and formation feedback response. It is widely used in downhole engineering operations such as oil and gas drilling, coalbed methane extraction, and shale gas exploration. Automatic drilling parameter control integrates sensor acquisition systems, control strategy algorithms, and data response mechanisms, enabling drilling equipment to adjust operating parameters according to real-time conditions in varying geological environments. This meets the drilling needs of different well sections and features highly integrated, intelligent, and adaptive systems, encompassing multiple levels including control principle design, parameter setting methods, feedback control logic, and multivariate regulation technology. Traditional coalbed methane downhole drilling parameter optimization methods refer to a type of operation where drilling parameters such as drill pressure, rotation speed, pump pressure, and drilling fluid flow rate are manually set based on experience or optimized through post-analysis to improve drilling efficiency and construction safety during coalbed methane well drilling. Traditional methods typically rely on manual adjustment of drilling parameters based on geological properties and historical construction experience, or on post-drilling analysis of data curves to summarize and propose optimization suggestions. These methods often involve on-site observation, segmented parameter recording, comparison with experience tables, and analogy with historical cases.

[0003] Existing technologies set drilling parameters based on on-site observation and historical experience, but lack the ability to accurately capture real-time formation response signals. This makes it difficult to form a dynamic alignment mechanism between data, and the parameter adjustment process cannot effectively reflect the linkage between drilling pressure and pump pressure. There are problems of separation of control and delayed response. When abnormal fluctuations occur during drilling, relying on manual judgment often makes it difficult to identify and control key points in a timely manner. This results in one-sided and delayed parameter settings, and the control actions cannot form a continuous logical chain. The synergistic effect between different parameters is weakened, affecting the construction rhythm and operational stability. Summary of the Invention

[0004] To achieve the above objectives, this invention proposes a method and system for optimizing drilling parameters in coalbed methane wells; wherein: A method for optimizing drilling parameters in coalbed methane wells includes the following steps: S1: Acquire the acoustic response signal installed below the drill bit, extract the arrival time of the reflected signal and calculate the propagation time delay based on the preset multi-point layout and excitation results, as well as the echo amplitude change value, and generate the acoustic propagation delay sequence in time order. S2: Collect the drilling pressure data stream corresponding to the acoustic propagation delay sequence, align and compare the change gradient and peak interval of the drilling pressure data stream and the acoustic propagation delay sequence in the same time period, identify the fluctuation pattern of acoustic parameters deviating from the preset reference range, and output the drilling pressure change trajectory. S3: Mark the time segments in the drilling pressure change trajectory where the upward slope exceeds the threshold, extract the pump pressure sampling records within the time segments, analyze the synchronicity between the rise and fall trends of the pump pressure sampling records and the drilling pressure change trajectory, and generate the pump pressure change trend. S4: Compare the drilling pressure change trajectory with the pump pressure change trend, and extract the combination of control actions that meet the linkage execution conditions based on the consistency in response delay, amplitude direction and change duration, and construct the construction control action sequence. S5: Based on the construction control action sequence, extract the control command content including drilling pressure adjustment action and pump pressure adjustment action, activate the control components of the drilling platform, drive the hardware response process, and form an optimized control process for coalbed methane downhole drilling construction parameters.

[0005] As a further aspect of the present invention, the acoustic propagation delay sequence includes propagation time difference, echo amplitude change value, and time series index; the drilling pressure change trajectory includes change gradient characteristics, peak interval characteristics, and trend coupling parameters; the pump pressure change trend includes numerical rise and fall amplitude, synchronization index, and time period label; the construction control action sequence includes response delay parameters, amplitude change direction identifier, and change duration; and the coalbed methane downhole drilling construction parameter optimization control process includes drilling pressure adjustment command, pump pressure adjustment command, and control component activation parameters.

[0006] As a further aspect of the present invention, the drilling pressure fluctuation mode corresponding to the abnormal sound wave refers to the fluctuation pattern in the drilling pressure change curve, in the time period corresponding to the sound wave propagation delay sequence, where a sharp increase in gradient and an abnormally shortened peak interval occur.

[0007] As a further aspect of the present invention, the linkage execution conditions refer to the conditions that the response delay of the drilling pressure control point and the pump pressure control point does not exceed a preset threshold, the amplitude direction is consistent, and the change is continuous.

[0008] As a further aspect of the present invention, the specific steps of S1 are as follows: S101: Acquire the acoustic response signal installed below the drill bit, extract the received timestamp of the signal packet, calculate the time difference between adjacent sampling points, and generate a propagation time difference sequence; S102: Call the propagation time difference sequence, extract the signal strength value in the signal packet, calculate the strength difference between adjacent sampling points, record the amplitude change of the nodes in sequence, and generate an echo amplitude change value sequence. S103: The propagation time difference sequence and the echo amplitude change value sequence are spliced ​​together according to their index order, and the time series of the nodes are sorted to generate the sound wave propagation delay sequence.

[0009] As a further aspect of the present invention, the specific steps of S2 are as follows: S201: Collect the drilling pressure data stream corresponding to the time axis of the acoustic wave propagation delay sequence, extract the drilling pressure value at each time node, compare the timestamps of the two sets of data according to the time axis, perform synchronization processing operation point by point, and establish a time-aligned drilling pressure sequence; S202: Call the time-aligned drill pressure sequence and the acoustic propagation delay sequence, calculate the gradient value of change and the interval parameter between adjacent peaks within the same time period, compare the synchronicity of the two sets of parameter curves, extract abnormal offset feature points, and obtain the corresponding features of drill pressure fluctuation; S203: Based on the characteristics of the drilling pressure fluctuation, collect the correspondence between the trend of acoustic wave change and the direction of drilling pressure change, perform point-by-point comparison of the direction of change of acoustic wave delay value and drilling pressure value within the same time period, determine the consistency of the two in the trend of change, and perform sequence splicing and trajectory mapping on the coupling matching interval to generate the drilling pressure change trajectory.

[0010] As a further aspect of the present invention, the specific steps of S3 are as follows: S301: Calculate the slope of the drilling pressure change at adjacent time nodes point by point in the drilling pressure change trajectory, compare the slope value with the preset slope threshold, filter out continuous time nodes with slope values ​​exceeding the slope threshold, and mark and aggregate the time to obtain high slope drilling pressure time segments. S302: Based on the time range of the high-inclination drilling pressure time segment, collect pump pressure sampling records within the corresponding time axis, and perform difference calculation on the pump pressure values ​​of adjacent sampling points to form a pump pressure rise and fall direction sequence. At the same time, perform synchronization sequence alignment on the drilling pressure values ​​to obtain a pump pressure and drilling pressure synchronization sequence. S303: Call the pump pressure and drilling pressure synchronization sequence, determine the consistency of the rising and falling direction of the pump pressure value in continuous time nodes, and arrange and serialize the nodes that meet the continuous change conditions in time order to generate the pump pressure change trend.

[0011] As a further aspect of the present invention, the specific steps of S4 are as follows: S401: Based on the control point information marked in the drilling pressure change trajectory and the pump pressure change trend, extract the response start time of each pair of control points, compare the time difference with the preset response delay threshold, and filter the control point pairs that meet the delay consistency condition to obtain a set of synchronous response control points. S402: Call the synchronous response control points to collect the amplitude change direction of drilling pressure and pump pressure, compare the change sign characteristics of the same control points, and make a judgment by combining the duration interval difference and the change duration threshold, filter point pairs that match the change direction and duration, and generate a linkage execution control combination; S403: Based on the start time of the control actions in the linkage execution control combination, sort all control actions in ascending order to establish a construction control action sequence.

[0012] As a further aspect of the present invention, the specific steps of S5 are as follows: S501: Based on the sorted control items in the construction control action sequence, extract the control type, adjustment target and adjustment range corresponding to each control action in sequence, and classify and record the actions belonging to the drilling pressure control category and the pump pressure control category respectively, and establish a control command parameter set; S502: Invoke the drilling pressure adjustment action and pump pressure adjustment action in the control command parameter set, retrieve the corresponding control component identifier in the drilling operation platform, align the control action with the corresponding hardware command through the command mapping rule, complete the component activation configuration, and generate a control component call list; S503: Based on the control command sequence and associated hardware response logic in the control component call list, execute the continuous control link activation operation, construct the closed-loop relationship between drilling pressure and pump pressure regulation in the time sequence chain, and establish the optimization control process for coalbed methane downhole drilling construction parameters.

[0013] A coalbed methane well downhole drilling parameter optimization system includes: The acoustic signal processing module is used to achieve S1: acquiring the acoustic response signal installed below the drill bit, extracting the arrival time of the reflected signal and calculating the propagation time delay based on the preset multi-point layout and excitation results, as well as the echo amplitude change value, and generating an acoustic propagation delay sequence in chronological order; The drilling pressure fluctuation identification module is used to implement S2: acquiring the drilling pressure data stream corresponding to the acoustic propagation delay sequence, aligning and comparing the change gradient and peak interval of the drilling pressure data stream and the acoustic propagation delay sequence in the same time period, identifying the fluctuation pattern of acoustic parameters deviating from the preset reference range, and outputting the drilling pressure change trajectory; The pump pressure synchronization analysis module is used to implement S3: mark the time segment in the drilling pressure change trajectory where the upward slope exceeds the threshold, extract the pump pressure sampling record within the time segment, analyze the synchronicity between the rise and fall trend of the pump pressure sampling record and the drilling pressure change trajectory, and generate the pump pressure change trend; The linkage control extraction module is used to achieve S4: compare the drilling pressure change trajectory with the pump pressure change trend, and extract the combination of control actions that meet the linkage execution conditions based on the consistency in response delay, amplitude direction and change duration, and construct the construction control action sequence. The intelligent control execution module is used to implement S5: based on the construction control action sequence, extract the control command content including drilling pressure adjustment action and pump pressure adjustment action, activate the control components of the drilling platform, drive the hardware response process, and form an optimized control process for coalbed methane downhole drilling construction parameters.

[0014] Compared with the prior art, the advantages and positive effects of the present invention are as follows: In this invention, by constructing a sound wave propagation delay sequence and synchronizing the drilling pressure response, the abnormal state is accurately calibrated. By combining the pump pressure change trend to identify key control segments, a temporal coupling relationship between drilling pressure and pump pressure is established. Control action combinations that meet response consistency are extracted and sequentially organized to form a continuous and targeted control instruction set. This enables the collaborative identification and linkage control of multi-parameter change trends, thereby improving the stability and response coordination during construction. Attached Figure Description

[0015] To more clearly illustrate the technical solutions in the embodiments of the present invention, the accompanying drawings used in the description of the embodiments will be briefly introduced below. Obviously, the accompanying drawings described below are only some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0016] Figure 1 This is a schematic diagram of the steps of the present invention; Figure 2 This is a detailed schematic diagram of S1 of the present invention; Figure 3 This is a detailed schematic diagram of S2 of the present invention; Figure 4 This is a detailed schematic diagram of S3 of the present invention; Figure 5 This is a detailed schematic diagram of S4 of the present invention; Figure 6 This is a detailed schematic diagram of S5 of the present invention; Figure 7 This is a system module diagram of the present invention. Detailed Implementation

[0017] The technical solution of the present invention will now be described with reference to the accompanying drawings.

[0018] In embodiments of the present invention, words such as "exemplarily," "for example," etc., are used to indicate that something is an example, illustration, or description. Any embodiment or design described as "exemplary" in the present invention should not be construed as being more preferred or advantageous than other embodiments or designs. Specifically, the use of the word "exemplary" is intended to present the concept in a concrete manner. Furthermore, in embodiments of the present invention, the meaning expressed by "and / or" can be both, or either one.

[0019] In the embodiments of this invention, the terms "image" and "picture" may sometimes be used interchangeably. It should be noted that, without emphasizing the distinction between them, they convey the same meaning. Similarly, the terms "of," "corresponding (relevant)," and "corresponding" may sometimes be used interchangeably. It should be noted that, without emphasizing the distinction between them, they convey the same meaning.

[0020] In this embodiment of the invention, sometimes a subscript such as W1 may be written in a non-subscript form such as W1. When the difference is not emphasized, the meaning they express is the same.

[0021] To make the technical problems, technical solutions and advantages of the present invention clearer, a detailed description will be given below in conjunction with the accompanying drawings and specific embodiments.

[0022] Please see Figure 1 This invention provides a method for optimizing drilling parameters in coalbed methane wells, comprising the following steps: S1: Acquire the acoustic response signal installed below the drill bit. Based on the arrival time and reflection intensity characteristics during the propagation of the acoustic wave, calculate the propagation time difference and echo amplitude change value between adjacent sampling points respectively. Arrange all results in chronological order to generate an acoustic wave propagation delay sequence. S2: Collect the drilling pressure data stream corresponding to the acoustic propagation delay sequence, perform synchronous alignment processing point by point, compare the change gradient and peak interval characteristics of the two sets of data in the same time period, identify the drilling pressure fluctuation pattern corresponding to the acoustic anomaly, and output the drilling pressure change trajectory through bidirectional trend coupling. S3: Mark the time segments in the drilling pressure change trajectory where the upward slope exceeds the preset slope threshold, and extract pump pressure sampling records within the same time range, analyze the continuous rise and fall trend of pump pressure values ​​and the synchronicity characteristics of drilling pressure, and generate pump pressure change trend according to time sorting method. S4: Based on the control point information marked in the drilling pressure change trajectory and pump pressure change trend, compare the consistency between the two in response delay, amplitude direction and change duration, extract the control action combination that meets the linkage execution conditions, and construct the construction control action sequence according to the control sequence. S5: Based on the construction control action sequence, extract the control command content, including drilling pressure adjustment action and pump pressure adjustment action, and activate the corresponding control components in the drilling operation platform. Drive the hardware response process through continuous control logic to form the coalbed methane downhole drilling construction parameter optimization control process.

[0023] The acoustic propagation delay sequence includes propagation time difference, echo amplitude change value, and time series index; the drilling pressure change trajectory includes change gradient characteristics, peak interval characteristics, and trend coupling parameters; the pump pressure change trend includes numerical rise and fall amplitude, synchronicity index, and time period label; the construction control action sequence includes response delay parameters, amplitude change direction identifier, and change duration; and the coalbed methane downhole drilling construction parameter optimization control process includes drilling pressure adjustment command, pump pressure adjustment command, and control component activation parameters.

[0024] Please see Figure 2 The specific steps of S1 are as follows: S101: Acquire the acoustic response signal installed below the drill bit, extract the received timestamp of the signal packet, calculate the time difference between adjacent sampling points, and generate a propagation time difference sequence; Multiple sets of high-sensitivity acoustic sensors need to be deployed directly below the drill bit. Each set of sensors is installed at equal intervals on an axis perpendicular to the drill bit to ensure real-time acquisition of acoustic information generated by the interaction between the drill bit and the formation during drilling. Each sensor needs to be encapsulated under high temperature and pressure to adapt to the complex downhole environment. After receiving the acoustic signal, the sensor performs preliminary amplification and filtering through a signal conditioning module, and then enters the data acquisition device for sampling. A unified time reference is set for sampling. Each set of sensors records the reception time at the instant the acoustic packet is acquired, forming a time-stamped sequence of signal packets. In actual operation, for example, a sampling rate of 2000 times per second can be set, and multiple timestamps of acoustic signal reception can be recorded during continuous drilling. By extracting signal peaks with significant reflection characteristics and combining them with their corresponding formation depth or trigger time information, the propagation time delay of each reflected signal is calculated, forming a propagation time delay sequence. In this process, constant time intervals generated solely by the sampling period should be excluded to avoid mistaking sampling jitter for changes in sound wave propagation. The calculated time differences should be recorded as a separate array, which is the propagation time difference sequence. To ensure its accuracy, outliers with time differences less than the minimum resolution or much higher than the reasonable propagation delay should be removed during processing. For example, if the time difference between two signals is less than 0.0001 seconds or greater than 0.01 seconds, it is considered an invalid signal. Normal data should be stored sequentially in a buffer and marked with real-time drill bit position information so that subsequent steps can further analyze the propagation path change trend, ultimately obtaining a propagation time difference sequence with a complete structure and time accuracy that meets processing requirements.

[0025] S102: Call the propagation time difference sequence, extract the signal strength value in the signal packet, calculate the strength difference between adjacent sampling points, record the amplitude change of the nodes in sequence, and generate the echo amplitude change value sequence. By reading the signal intensity data from the acoustic signal packet corresponding to each time difference, where the intensity value is the maximum voltage response or average effective value of the acoustic signal received by the sensor within a specific time period, the original signal waveform needs to be shaped and normalized first to remove abnormal peak values ​​caused by electromagnetic interference or environmental fluctuations. Then, the effective data points in each signal packet are extracted at equal intervals, and the point with the largest amplitude is selected as the representative intensity value of that packet. After obtaining the entire intensity value sequence, the intensity values ​​of two adjacent signal packets are processed by difference, that is, the intensity of the later signal packet is subtracted from the intensity of the earlier signal packet and the absolute value is taken. This process is repeated for the entire sequence. The above operation is performed on each pair of signal packets in the sequence, and the difference obtained is the amplitude change. In actual operation, for example, in a drilling task, the amplitude values ​​of two adjacent sampling points are 1.8 volts and 2.1 volts, respectively, and the difference between them is 0.3 volts. If the difference is less than the set minimum change threshold, such as 0.05 volts, it is not counted as valid data. Otherwise, it is recorded as an amplitude change and stored in the amplitude change value sequence. At the same time, the index information of the original propagation time difference is attached when recording to maintain the consistency of the data source. The data is numbered according to the chronological order of the time series to form a complete echo amplitude change value sequence. This sequence will participate in time delay analysis processing in subsequent steps.

[0026] S103: Concatenate the propagation time difference sequence and the echo amplitude change value sequence according to their index order, organize the time series of the nodes, and generate the sound wave propagation delay sequence; First, the index numbers of the two sequences are checked one by one to confirm that each time difference value has a corresponding amplitude change value, and that the sequence numbers are consistent and there are no missing values, ensuring that the data maintains logical pairing consistency. Then, according to the order of each item in the time difference sequence, the corresponding amplitude change values ​​are merged and recorded sequentially. Each merged data includes one time difference and one amplitude change. For example, in the 10th index number, the time difference is 0.002 seconds and the amplitude change is 0.35 volts, so it is merged into a data point (0.002 seconds, ...). (0.35 volts) and so on, all data are traversed and merged to obtain a complete node time series. During this process, a verification mechanism is set up to judge the validity of the time difference and amplitude change values ​​in all spliced ​​data. For example, if the time difference of a certain data point is lower than the minimum processing threshold, such as 0.0001 seconds, or the amplitude change is lower than 0.05 volts, the data point is removed to avoid invalid or abnormal data affecting the final analysis accuracy. All valid data points are arranged in ascending order of time difference, renumbered, and constitute a new acoustic wave propagation delay sequence. This sequence has a clear time order and corresponding reflection intensity characteristics, providing structured time domain input data for the response of the drill bit to the formation medium at different drilling depths.

[0027] Please see Figure 3 The specific steps of S2 are as follows: S201: Collect the drill pressure data stream corresponding to the time axis of the acoustic propagation delay sequence, extract the drill pressure value at each time node, compare the timestamps of the two sets of data according to the time axis, perform synchronization processing operation point by point, and establish a time-aligned drill pressure sequence; First, drilling pressure data is acquired in real time using a drilling pressure sensor mounted on the drill string. This sensor continuously outputs instantaneous values ​​reflecting the pressure exerted on the drill bit, in kN. The data output frequency is set to 1Hz, meaning one drilling pressure value is generated per second. A time synchronization module provides a unified clock source for both the drilling pressure acquisition module and the acoustic wave propagation sequence acquisition module. While acquiring the drilling pressure data stream, a corresponding timestamp is added to each drilling pressure value, recorded in "hours, minutes, seconds, milliseconds" format. Then, the time point information in the acoustic wave propagation delay sequence is extracted, and these time points are scanned one by one. The drilling pressure data stream is searched for the closest timestamp. If the time difference between the two does not exceed the set synchronization tolerance threshold, for example, 0.5 seconds, the two time points are considered to be successfully matched, and the drilling pressure value is used as the corresponding acoustic wave time segment. If the time difference between the synchronous drill pressure values ​​at a point exceeds a set threshold, the next time point is searched forward or backward in the drill pressure sequence, and it is determined whether its error meets the condition. If it does, the point is selected as the replacement; otherwise, it is considered data loss and no matching is performed. After completing point by point, the drill pressure values ​​corresponding to the successfully matched time points are rearranged according to the time order of the acoustic propagation delay sequence, and their original time error and sampling value information are recorded to form a time-aligned drill pressure sequence. For example, in a certain sampling segment, the time point of the acoustic sequence is 432.500 seconds, and the timestamp of the corresponding drill pressure data is 432.467 seconds, with an error of 0.033 seconds, which is less than the tolerance threshold, so the match is successful. Finally, a drill pressure data sequence that completely corresponds to the acoustic propagation delay sequence and has the same time axis is formed, which is used for subsequent joint feature analysis.

[0028] S202: Call the time-aligned drill pressure sequence and the acoustic propagation delay sequence, calculate the gradient value of change and the interval parameter between adjacent peaks within the same time period, compare the synchronicity of the two sets of parameter curves, extract abnormal offset feature points, and obtain the corresponding features of drill pressure fluctuation. First, based on the time sequence of the two sets of data, several consecutive data points within the same interval are selected to form an analysis segment. For example, 50 data points are selected within a 50-second time period. Each pair of adjacent data points in the drilling pressure sequence and the sonic delay sequence is processed separately, and the gradient value is calculated, which is the ratio of the difference between the values ​​of each pair of adjacent points to the time interval, to construct the rate of change sequence. In the drilling pressure sequence, if two points are 102kN and 108kN respectively, with a time interval of 1 second, the gradient value is 6kN / s. If the corresponding data in the sonic delay sequence are 0.0017s and 0.0020s, the gradient is 0.0003s / s. This process is repeated to obtain the complete gradient sequence for each set of data. Then, peaks are determined in each gradient sequence by detecting local maxima or minima. The method uses a window approach to determine if the midpoint of every five data points is greater than the two points before and after it, thus identifying a local peak. The time position and value of all peaks are recorded, and the time interval between adjacent peaks is calculated to form an interval parameter sequence. For example, the interval between drilling pressure peaks is 12 seconds, and the interval between sonic peaks is 13 seconds, with a difference of 1 second. If a synchronization threshold of 2 seconds is set, then this pair of interval parameters is considered synchronized. This comparison is repeated for all other peak pairs, and points that do not meet the synchronization condition are recorded. If the difference in a set of interval parameters exceeds 2 seconds, for example, 5 seconds, then that time point is considered an abnormal offset point. The corresponding drilling pressure value and sonic delay value are extracted to form an abnormal feature point set, ultimately obtaining key point data showing asynchrony or abrupt changes during drilling pressure fluctuations, which serve as the corresponding features of drilling pressure fluctuations.

[0029] S203: Based on the characteristics of drilling pressure fluctuation, collect the correspondence between the trend of sonic wave change and the direction of drilling pressure change, perform point-by-point comparison of the direction of change of sonic wave delay value and drilling pressure value within the same time period, determine the consistency of the two in the trend of change, and perform sequence splicing and trajectory mapping on the coupling matching interval to generate the drilling pressure change trajectory. In the aligned drill pressure sequence and acoustic propagation delay sequence, equal time intervals are selected, and trend direction analysis is performed on both sets of data. Adjacent data points are compared; if the later value is greater than the earlier value, it is considered an upward trend; otherwise, a downward trend. If they are equal, it is considered a stable trend, forming a trend direction sequence. For example, in the drill pressure sequence, three consecutive data points of 105kN, 110kN, and 114kN constitute two upward trends. In the acoustic sequence, if the corresponding time intervals are 0.0019s, 0.0023s, and 0.0026s, also an upward trend, it is determined to be a positive trend coupling. If the two directions are inconsistent, such as drill pressure increasing while acoustic propagation delay decreases, it is determined to be a trend inconsistency. This rule is applied to the entire data sequence. The process involves segment-by-segment judgment, recording and marking coupling intervals within each time period with a consistent trend. For each coupling interval, the drill pressure and acoustic wave values ​​at its start and end points are extracted and spliced ​​together to form a combined sequence. Continuous data segments are then constructed on the time axis in seconds. For example, a coupling segment is formed from the 400th second to the 412th second, where the drill pressure increases from 98kN to 125kN and the acoustic wave delay increases from 0.0015s to 0.0029s. These two sets of values ​​together constitute a positive coupling segment. Subsequently, multiple coupling segments are connected in chronological order to form a continuous trajectory segment. The drill pressure value is used as the vertical axis and time as the horizontal axis to draw a trajectory line, forming a trajectory image reflecting the trend of drill pressure changes. Finally, a structured drill pressure change trajectory is output.

[0030] Please see Figure 4 The specific steps of S3 are as follows: S301: Calculate the slope of the drilling pressure change at adjacent time nodes point by point in the drilling pressure change trajectory, compare the slope value with the preset slope threshold, filter out continuous time nodes with slope values ​​exceeding the slope threshold, and mark and aggregate them to obtain high slope drilling pressure time segments. First, the drill pressure (DP) values ​​and corresponding time intervals for all consecutive time nodes in the drill pressure variation trajectory are read. For every two adjacent time nodes, the DP value of the later node is subtracted from the DP value of the earlier node, and then divided by the time interval to obtain the slope value for that time interval. This calculation is performed in seconds. For example, if the DP is 115 kN at one node and 125 kN at the next node, with a time interval of 1 second, the corresponding slope is 10 kN / s. This slope calculation operation is performed point by point along the entire trajectory in this manner, and all the calculated slope values ​​are combined into a slope sequence. Then, a preset slope threshold is called and compared with each slope value. The slope threshold is a set critical index for judging drastic changes, and this value is referenced to the stable DP value in conventional downhole drilling. The variable range is set, generally to 8 kN / s. If a slope value is greater than or equal to this threshold, it is judged as a high slope node; if it is less than the threshold, it is ignored. The filtering process continuously judges according to the index order. Whenever three or more consecutive nodes meet the condition that the slope is greater than or equal to the threshold, it is judged as a continuous high slope segment, and its start time index and end time index are marked. For example, if the slope values ​​of six consecutive points between 110 and 115 seconds are 9, 10, 11, 13, 12, and 8 kN / s, it constitutes a valid high slope segment. All slope values ​​in this time segment are aggregated and recorded, and the time range, start and end drilling pressure values, and average slope of this segment are saved as segment identification parameters, ultimately forming a high slope drilling pressure time segment.

[0031] S302: Based on the time range of the high-inclination drilling pressure time segment, collect pump pressure sampling records within the corresponding time axis, and perform difference calculation on the pump pressure values ​​of adjacent sampling points to form a pump pressure rise and fall direction sequence. At the same time, perform synchronization sequence alignment on the drilling pressure values ​​to obtain the pump pressure and drilling pressure synchronization sequence. First, locate the time index values ​​corresponding to the start and end points of a time segment. For example, if the start point of a segment is 220 seconds and the end point is 232 seconds, then use this time range as the index range to read all pump pressure sampling points within the corresponding time period in the pump pressure data acquisition sequence. Each point represents the pump pressure value recorded once per second, in MPa. The pump pressure values ​​extracted within this range are arranged chronologically to form a pump pressure sampling record sequence. Then, perform a difference calculation between adjacent sampling points on this sequence. For example, if the pump pressure at 221 seconds is 12.4 MPa and the pump pressure at 222 seconds is 13.1 MPa, the difference is 0.7 MPa, indicating an upward trend. If the later value is less than the earlier value, it indicates a downward trend; if the difference is equal to 0, it indicates a stable trend. Compare each pair to form a sequence of pump pressure rise and fall directions. If a directional sequence is obtained within a certain segment as "rising, rising, falling, falling, stable, rising", it is recorded as a text tag, with each direction corresponding to a specific start time point and difference value. At the same time, the drilling pressure data within this time segment is synchronized, and the drilling pressure value that is completely consistent with the pump pressure sampling time within this segment is extracted to form a drilling pressure alignment sequence. For example, if the pump pressure sampling is at 223 seconds, then the drilling pressure value at 223 seconds is read from the original drilling pressure sequence and synchronized accordingly. If there is no corresponding item at a time point, the nearest value with a time error of less than 0.5 seconds is searched forward and backward to replace it. After completion, the pump pressure directional sequence and the drilling pressure sequence are arranged to form a pump pressure and drilling pressure synchronization sequence. Each item in this sequence consists of a pump pressure value, a drilling pressure value, and a pump pressure rise and fall trend, which is used for subsequent trend consistency analysis.

[0032] S303: Call the pump pressure and drilling pressure synchronization sequence, determine the consistency of the rise and fall direction of the pump pressure value in continuous time nodes, and arrange and serialize the nodes that meet the continuous change conditions in time order to generate the pump pressure change trend. The process analyzes whether the rising and falling directions of consecutive time nodes in the pump pressure sequence remain consistent. During execution, a judgment window is set to 3 seconds, meaning that the pump pressure rising and falling directions of three consecutive data points are the same. If there are three consecutive "rising" or three consecutive "falling" markers, the direction of that segment is considered consistent. During the judgment, the window slides backward from the beginning of the sequence, updating the direction comparison point by point to determine whether the condition is met. For example, if the direction sequence is "rising, rising, rising, stable, falling, falling, falling", then it is divided into two consistent segments. After confirming that the direction is consistent, the start and end points of the consistent direction of each segment are extracted, and all nodes that meet the continuous change condition are arranged according to the time order. These nodes are renumbered in ascending order of time, and each segment is assigned a unique serialized code identifier, such as "segment A", "segment B", etc. Each node in the segment code is accompanied by its time index, pump pressure value, drilling pressure value, and change direction identifier. Finally, all segments that meet the conditions are combined to form a complete pump pressure change trend. This trend is output in text and numerical structure, reflecting the direction, magnitude, and continuity of pump pressure change within a specific time period.

[0033] Please see Figure 5 The specific steps of S4 are as follows: S401: Based on the control point information marked in the drilling pressure change trajectory and pump pressure change trend, extract the response start time of each pair of control points, compare the time difference with the preset response delay threshold, and filter the control point pairs that meet the delay consistency condition to obtain the synchronous response control point set. First, extract the time index set marked as control points in the drilling pressure trajectory and the corresponding control point index set in the pump pressure trend. Each control point contains the time information of the start of the change, the magnitude of the corresponding value change, and the direction of change. For example, a drilling pressure control point is recorded as starting time 210 seconds, change magnitude +18kN, and direction upward; the pump pressure control point is recorded as starting time 213 seconds, change magnitude +2.4MPa, and direction upward. Each pair of drilling pressure and pump pressure control points is compared one by one. In the comparison step, first extract the start time of the two items in each pair and calculate the time difference Δt. This difference is obtained by direct subtraction. For example, if the start times of the two items are... If the time difference between two control actions is 210 seconds and 213 seconds, then Δt = 3 seconds. Subsequently, the preset response delay threshold is invoked. This threshold is set according to the drilling equipment control feedback mechanism and is generally 5 seconds. This means that if the time difference between two control actions is less than or equal to 5 seconds, they are considered to have response synchronization characteristics. When performing the comparison, Δt is judged against the threshold. If Δt ≤ 5 seconds, the point pair is retained; otherwise, it is discarded. This judgment process is repeated in all control point combinations. After one round of comparison, all control point pairs that meet the response delay consistency are summarized. For each point pair that meets the condition, the start time, change direction, and amplitude of drilling pressure and pump pressure are recorded for subsequent linkage judgment and processing. Finally, a set of synchronous response control points is obtained.

[0034] S402: Call the synchronous response control point to collect the amplitude change direction of drilling pressure and pump pressure, compare the change sign characteristics of the same control point, and make a judgment based on the difference in duration interval and the change duration threshold. Select point pairs that match the change direction and duration, and generate a linkage execution control combination. First, the change sign of each pair of synchronous control points is extracted. If the two changes are in the same direction, they are considered to have the same sign. For example, if the drilling pressure changes by +18kN and the pump pressure changes by +2.1MPa, both are positive changes. If one is positive and the other is negative, they are in opposite directions. This is used to determine the matching of change signs. The matching standard is that if the directions are the same, it is positively correlated; if they are not the same, it is uncorrelated. Then, the duration interval of each pair of control points is extracted, that is, the interval from the start time of the change to the end time of the change. For example, if the duration of the drilling pressure change is 8 seconds and the duration of the pump pressure change is 9 seconds, the time difference is 1 second. The set change duration threshold is then used for comparison and judgment. This threshold represents the maximum acceptable range of duration difference between the two, generally set to 3 seconds. If the duration difference between the two is within this threshold range and the signs of the change direction are consistent, then the pair of control points is judged to meet the linkage control standard. This process is performed once for each pair of data in the synchronous control point set, recording all point pairs that meet the conditions, and marking their start time, drilling pressure change amplitude, pump pressure change amplitude, duration, and direction type. For example, a certain combination point is recorded as having a start time of 221 seconds, drilling pressure +22kN, pump pressure +3.0MPa, durations of 8 seconds and 9 seconds respectively, both with an upward change direction and a time difference of 1 second, which meets the conditions and is included in the linkage execution control combination.

[0035] S403: Based on the start time of the control actions in the linkage execution control combination, sort all control actions in ascending order to establish a construction control action sequence; The start time values ​​of drilling pressure control and pump pressure control actions are extracted from each combination, and these time points are uniformly converted into absolute second value indices. Then, all control combinations are sorted in ascending order of start time. If two combinations have the same start time, the pump pressure control action is prioritized before the drilling pressure control action. An ascending queue is established to ensure that the execution of control actions has a clear sequential logical structure. Each record in the queue is accompanied by complete action identification information, including start time, direction of change of control parameters, change amplitude, and duration, to support subsequent scheduling module calls. For example, if the first three action records in the queue are as follows: start time 205 seconds, pump pressure +1.8MPa, duration 5 seconds; start time 206 seconds, drilling pressure +15kN, duration 6 seconds; start time 211 seconds, pump pressure -2.5MPa, duration 7 seconds, then an ascending order control action sequence is formed, ultimately creating a construction control action sequence covering the entire process.

[0036] Please see Figure 6 The specific steps of S5 are as follows: S501: Based on the sorted control items in the construction control action sequence, extract the control type, adjustment target and adjustment range corresponding to each control action in sequence, and classify and record the actions belonging to the drilling pressure control category and the pump pressure control category respectively, and establish a control command parameter set; From each control record, three items are extracted sequentially: control type, adjustment target, and adjustment range. The control type is defined by the action label and is divided into two categories: "Drill Pressure Adjustment" and "Pump Pressure Adjustment." The adjustment target is the specified desired value or target operating state. The adjustment range is the numerical change of the current action compared to the previous state. For example, if a control item record is "Type: Drill Pressure Adjustment, Target: 120kN, Range: +15kN," it means that the control item intends to increase the drill pressure by 15kN to reach the target of 120kN. After reading all sorted control items, a classification operation is performed based on the control type field. All actions marked as drill pressure adjustment are extracted and arranged into a group in chronological order. All actions marked as pump pressure regulation are extracted and stored separately in another group. During the classification process, each control item is reassigned a unique number to identify its category, time index, and parameter value, which facilitates subsequent equipment allocation and instruction distribution. In addition, to avoid conflicts caused by overlapping control actions, the time interval between adjacent control actions is detected during classification. If the interval between adjacent actions is less than the set minimum control interval threshold (e.g., 3 seconds), it is marked as an overlapping item that needs to be adjusted and is temporarily suspended when the final control parameter set is established. Finally, a control instruction parameter set consisting of two independent subsets is generated. Each subset contains three structured parameter records: control type with clear time sequence, adjustment target, and adjustment range.

[0037] S502: Call the drilling pressure adjustment action and pump pressure adjustment action in the control command parameter set, retrieve the corresponding control component identifier in the drilling operation platform, align the control action with the corresponding hardware command through the command mapping rule, complete the component activation configuration, and generate a control component call list; Each instruction record is iterated sequentially, and the corresponding control component identifier is retrieved from the equipment resource mapping table of the drilling platform. This identifier consists of the hardware component's equipment number and its sub-code. For example, the drilling pressure adjustment action corresponds to the downhole pressurization module number "DA-03", and the pump pressure adjustment action corresponds to the surface pump control device number "PB-05". The corresponding component set is directly retrieved based on the control type field, and a mapping relationship is established with the target parameter and adjustment range in the control item. Then, the control action is converted into an instruction format according to the instruction mapping rules. For example, a drilling pressure adjustment action with an adjustment range of +12kN will be mapped to "SET_DA-03:INC_12", where "SET" indicates the control type. The command identifier, "DA-03" is the device number, and "INC_12" is the specific action content. Pump pressure actions are identified by "INC" or "DEC" depending on whether they are pressurization or depressurization. After the command mapping is completed, each command is bound to the corresponding hardware component to generate an activation list. Each record in the list includes a time index, component number, target parameters, command content, and an identifier parameter indicating whether a confirmation receipt is required. If the current device exists and is in standby mode, it directly enters the configuration stage and activates the component port. If the device does not respond or is not online, it is marked as abnormal and the current record is removed for subsequent adjustments. Finally, a complete list of control components is formed for the activation stage of the control link to call.

[0038] S503: Based on the order of control instructions in the list of control components and the associated hardware response logic, execute the continuous control link activation operation, construct the closed-loop relationship between drilling pressure and pump pressure regulation in the time chain, and establish the optimization control process for coalbed methane downhole drilling construction parameters. Read each instruction record from the beginning of the list in ascending chronological order, and activate the drilling pressure control link and pump pressure control link according to the control type. During execution, first check if the triggering condition of the control action is met at the current moment. If it is, send the control instruction to the corresponding hardware component. After receiving the instruction, the component enters the response preparation state and determines whether it sends back status feedback within the specified response time according to the equipment response logic. If the feedback is normal, the control action is confirmed to be completed, and the process of the next control instruction begins. If the feedback is abnormal or there is no feedback after timeout, the component is marked as abnormal, the current instruction is skipped, and the subsequent instruction is executed. The drilling pressure control action in the link control logic must be continuously maintained for at least two seconds. For pump pressure control actions, the feedback stability value is required to ensure that the value fluctuation does not exceed the set fluctuation range of ±0.2MPa within three consecutive seconds. The start time and feedback confirmation time of each control action are recorded. After all command sequences are executed, the response intervals between all control actions are analyzed. If all actions are activated within the response time window without any boundary crossing, the link activation is determined to be complete. This control chain is recorded as a complete execution batch. A structured control link log is generated based on the sequence of each control action and the feedback response. Through this log, the closed-loop process of each adjustment action of drilling pressure and pump pressure in the execution sequence can be traced back step by step, thereby establishing an optimized control process for coalbed methane downhole drilling construction parameters.

[0039] Please see Figure 7 A coalbed methane well downhole drilling parameter optimization system, comprising: The acoustic signal processing module is used to achieve S1: acquiring the acoustic response signal installed below the drill bit, extracting the arrival time of the reflected signal and calculating the propagation time delay based on the preset multi-point layout and excitation results, as well as the echo amplitude change value, and generating an acoustic propagation delay sequence in chronological order; The drilling pressure fluctuation identification module is used to achieve S2: to collect the drilling pressure data stream corresponding to the acoustic propagation delay sequence, align and compare the change gradient and peak interval of the drilling pressure data stream and the acoustic propagation delay sequence in the same time period, identify the fluctuation pattern of acoustic parameters deviating from the preset reference range, and output the drilling pressure change trajectory. The pump pressure synchronization analysis module is used to implement S3: mark the time segment in the drilling pressure change trajectory where the upward slope exceeds the threshold, extract the pump pressure sampling record within the time segment, analyze the synchronicity between the rise and fall trend of the pump pressure sampling record and the drilling pressure change trajectory, and generate the pump pressure change trend. The linkage control extraction module is used to achieve S4: compare the drilling pressure change trajectory with the pump pressure change trend, and extract the combination of control actions that meet the linkage execution conditions in terms of consistency in response delay, amplitude direction and change duration, and construct the construction control action sequence. The intelligent control execution module is used to implement S5: based on the construction control action sequence, it extracts the control command content including drilling pressure adjustment action and pump pressure adjustment action, activates the control components of the drilling platform, drives the hardware response process, and forms an optimized control process for coalbed methane downhole drilling construction parameters.

[0040] The above description is merely a specific embodiment of the present invention, but the scope of protection of the present invention is not limited thereto. Any variations or substitutions that can be easily conceived by those skilled in the art within the technical scope disclosed in the present invention should be included within the scope of protection of the present invention. Therefore, the scope of protection of the present invention should be determined by the scope of the claims.

Claims

1. A method for optimizing drilling parameters in coalbed methane wells, characterized in that, Includes the following steps: S1: Acquire the acoustic response signal installed below the drill bit, extract the arrival time of the reflected signal and calculate the propagation time delay based on the preset multi-point layout and excitation results, as well as the echo amplitude change value, and generate the acoustic propagation delay sequence in time order. S2: Collect the drilling pressure data stream corresponding to the acoustic propagation delay sequence, align and compare the change gradient and peak interval of the drilling pressure data stream and the acoustic propagation delay sequence in the same time period, identify the fluctuation pattern of acoustic parameters deviating from the preset reference range, and output the drilling pressure change trajectory. S3: Mark the time segments in the drilling pressure change trajectory where the upward slope exceeds the threshold, extract the pump pressure sampling records within the time segments, analyze the synchronicity between the rise and fall trends of the pump pressure sampling records and the drilling pressure change trajectory, and generate the pump pressure change trend. S4: Compare the drilling pressure change trajectory with the pump pressure change trend, and extract the combination of control actions that meet the linkage execution conditions based on the consistency in response delay, amplitude direction and change duration, and construct the construction control action sequence. S5: Based on the construction control action sequence, extract the control command content including drilling pressure adjustment action and pump pressure adjustment action, activate the control components of the drilling platform, drive the hardware response process, and form an optimized control process for coalbed methane downhole drilling construction parameters.

2. The method for optimizing coalbed methane downhole drilling parameters according to claim 1, characterized in that, The acoustic propagation delay sequence includes propagation time difference, echo amplitude change value, and time series index; the drilling pressure change trajectory includes change gradient characteristics, peak interval characteristics, and trend coupling parameters; the pump pressure change trend includes numerical rise and fall amplitude, synchronization index, and time period label; the construction control action sequence includes response delay parameters, amplitude change direction identifier, and change duration; and the coalbed methane downhole drilling construction parameter optimization control process includes drilling pressure adjustment command, pump pressure adjustment command, and control component activation parameters.

3. The method for optimizing coalbed methane downhole drilling parameters according to claim 1, characterized in that, The linkage execution conditions refer to the conditions that the response delay of the drilling pressure control point and the pump pressure control point does not exceed a preset threshold, the amplitude direction is consistent, and the change is continuous.

4. The method for optimizing coalbed methane downhole drilling parameters according to claim 1, characterized in that, The specific steps of S1 are as follows: S101: Acquire the acoustic response signal installed below the drill bit, extract the received timestamp of the signal packet, calculate the time difference between adjacent sampling points, and generate a propagation time difference sequence; S102: Call the propagation time difference sequence, extract the signal strength value in the signal packet, calculate the strength difference between adjacent sampling points, record the amplitude change of the nodes in sequence, and generate an echo amplitude change value sequence. S103: The propagation time difference sequence and the echo amplitude change value sequence are spliced ​​together according to their index order, and the time series of the nodes are sorted to generate the sound wave propagation delay sequence.

5. The method for optimizing coalbed methane downhole drilling parameters according to claim 1, characterized in that, The specific steps of S2 are as follows: S201: Collect the drilling pressure data stream corresponding to the time axis of the acoustic wave propagation delay sequence, extract the drilling pressure value at each time node, compare the timestamps of the two sets of data according to the time axis, perform synchronization processing operation point by point, and establish a time-aligned drilling pressure sequence; S202: Call the time-aligned drill pressure sequence and the acoustic propagation delay sequence, calculate the gradient value of change and the interval parameter between adjacent peaks within the same time period, compare the synchronicity of the two sets of parameter curves, extract abnormal offset feature points, and obtain the corresponding features of drill pressure fluctuation; S203: Based on the characteristics of the drilling pressure fluctuation, collect the correspondence between the trend of acoustic wave change and the direction of drilling pressure change, perform point-by-point comparison of the direction of change of acoustic wave delay value and drilling pressure value within the same time period, determine the consistency of the two in the trend of change, and perform sequence splicing and trajectory mapping on the coupling matching interval to generate the drilling pressure change trajectory.

6. The method for optimizing coalbed methane downhole drilling parameters according to claim 1, characterized in that, The specific steps for S3 are as follows: S301: Calculate the slope of the drilling pressure change at adjacent time nodes point by point in the drilling pressure change trajectory, compare the slope value with the preset slope threshold, filter out continuous time nodes with slope values ​​exceeding the slope threshold, and mark and aggregate the time to obtain high slope drilling pressure time segments. S302: Based on the time range of the high-inclination drilling pressure time segment, collect pump pressure sampling records within the corresponding time axis, and perform difference calculation on the pump pressure values ​​of adjacent sampling points to form a pump pressure rise and fall direction sequence. At the same time, perform synchronization sequence alignment on the drilling pressure values ​​to obtain a pump pressure and drilling pressure synchronization sequence. S303: Call the pump pressure and drilling pressure synchronization sequence, determine the consistency of the rising and falling direction of the pump pressure value in continuous time nodes, and arrange and serialize the nodes that meet the continuous change conditions in time order to generate the pump pressure change trend.

7. The method for optimizing coalbed methane downhole drilling parameters according to claim 1, characterized in that, The specific steps of S4 are as follows: S401: Based on the control point information marked in the drilling pressure change trajectory and the pump pressure change trend, extract the response start time of each pair of control points, compare the time difference with the preset response delay threshold, and filter the control point pairs that meet the delay consistency condition to obtain a set of synchronous response control points. S402: Call the synchronous response control points to collect the amplitude change direction of drilling pressure and pump pressure, compare the change sign characteristics of the same control points, and make a judgment by combining the duration interval difference and the change duration threshold, filter point pairs that match the change direction and duration, and generate a linkage execution control combination; S403: Based on the start time of the control actions in the linkage execution control combination, sort all control actions in ascending order to establish a construction control action sequence.

8. The method for optimizing coalbed methane downhole drilling parameters according to claim 1, characterized in that, The specific steps of S5 are as follows: S501: Based on the sorted control items in the construction control action sequence, extract the control type, adjustment target and adjustment range corresponding to each control action in sequence, and classify and record the actions belonging to the drilling pressure control category and the pump pressure control category respectively, and establish a control command parameter set; S502: Invoke the drilling pressure adjustment action and pump pressure adjustment action in the control command parameter set, retrieve the corresponding control component identifier in the drilling operation platform, align the control action with the corresponding hardware command through the command mapping rule, complete the component activation configuration, and generate a control component call list; S503: Based on the control command sequence and associated hardware response logic in the control component call list, execute the continuous control link activation operation, construct the closed-loop relationship between drilling pressure and pump pressure regulation in the time sequence chain, and establish the optimization control process for coalbed methane downhole drilling construction parameters.

9. A coalbed methane well downhole drilling parameter optimization system, characterized in that, The system is used to implement the method for optimizing coalbed methane downhole drilling construction parameters according to any one of claims 1-8, the system comprising: The acoustic signal processing module is used to achieve S1: acquiring the acoustic response signal installed below the drill bit, extracting the arrival time of the reflected signal and calculating the propagation time delay based on the preset multi-point layout and excitation results, as well as the echo amplitude change value, and generating an acoustic propagation delay sequence in chronological order; The drilling pressure fluctuation identification module is used to implement S2: acquiring the drilling pressure data stream corresponding to the acoustic propagation delay sequence, aligning and comparing the change gradient and peak interval of the drilling pressure data stream and the acoustic propagation delay sequence in the same time period, identifying the fluctuation pattern of acoustic parameters deviating from the preset reference range, and outputting the drilling pressure change trajectory; The pump pressure synchronization analysis module is used to implement S3: mark the time segment in the drilling pressure change trajectory where the upward slope exceeds the threshold, extract the pump pressure sampling record within the time segment, analyze the synchronicity between the rise and fall trend of the pump pressure sampling record and the drilling pressure change trajectory, and generate the pump pressure change trend; The linkage control extraction module is used to achieve S4: compare the drilling pressure change trajectory with the pump pressure change trend, and extract the combination of control actions that meet the linkage execution conditions based on the consistency in response delay, amplitude direction and change duration, and construct the construction control action sequence. The intelligent control execution module is used to implement S5: based on the construction control action sequence, extract the control command content including drilling pressure adjustment action and pump pressure adjustment action, activate the control components of the drilling platform, drive the hardware response process, and form an optimized control process for coalbed methane downhole drilling construction parameters.

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