A digital twin monitoring system for drilling and workover equipment

Abstract

The present application relates to the technical field of digital twinning, in particular to a drilling and workover equipment digital twinning monitoring system, which comprises a deposition path reconstruction module, a trend section identification module, a differential pressure offset positioning module, a shock linkage analysis module and a joint control sequence generation module. In the present application, by constructing the corresponding relationship between the cuttings return path and the drilling depth time sequence, fusing the particle radial deformation and the liquid flow channel positioning information, forming the spatial mapping atlas of the deposition trajectory, combining the drilling speed amplitude trend of the trajectory dense section, extracting the continuous evolution section and constructing the trend distribution set, identifying the interlayer abnormal point based on the pressure sequence difference value amplitude change, further superimposing the consistency relationship between the drilling tool shock amplitude and the drilling speed variation direction, screening the linkage feature group with relevance, extracting the key nodes according to the trigger frequency and amplitude concentration, generating the corresponding operation instruction, and driving the multi-parameter collaborative identification and the intelligent generation of the drilling and workover control path.

Description

Technical Field

[0001] This invention relates to the field of digital twin technology, and in particular to a digital twin monitoring system for drilling and well workover equipment. Background Technology

[0002] Digital twin technology involves constructing virtual mappings of physical entities to achieve real-time monitoring, modeling, and control of industrial equipment, systems, or processes. Its core aspects include data acquisition and integration, modeling and simulation, state prediction, remote control, and decision support. This technology is widely used in industries such as manufacturing, energy, transportation, construction, and oil and gas to achieve digital mapping and dynamic feedback of actual operating states, playing a significant role in improving system operating efficiency, ensuring equipment safety, and supporting decision-making. Digital twin technology typically relies on real-time data collected by IoT sensing devices. After multi-source fusion processing, this data is input into the simulation model for dynamic updates, thereby achieving collaborative operation between the physical and digital worlds. Traditional drilling and workover monitoring systems refer to real-time monitoring of well site operations through the installation of sensors, cameras, and manual inspections. The main technical aspects targeted are monitoring changes in working conditions and identifying operational status during drilling or workover. Traditional methods typically involve collecting sensor signals at fixed points and displaying changes in on-site parameters centrally through a graphical interface to assist engineers in making judgments and taking actions. They generally collect on-site information by deploying wellhead pressure sensors, rotation speed measuring devices, mud flow sensors, and cameras, and then the control terminal analyzes and displays the parameters.

[0003] Existing technologies rely on single-point information acquisition from surface sensors at the well site, with monitoring primarily focused on static parameter displays. They lack the ability to track the dynamic behavior of downhole sedimentary particles and cannot establish a linkage model between sedimentary state and drill string response in the vertical dimension of drilling depth. In complex formations, they cannot determine the trend relationship between sediment accumulation and drilling rate changes, resulting in a lack of basis for drill string response adjustments. When drilling pressure disturbances or sudden pressure differentials occur, the system cannot identify the source and structure of the disturbance, which can easily lead to misjudgments or delayed intervention. For example, during periods of drastic changes in oscillation amplitude, static values ​​shown on the graphical interface alone are insufficient to support subsequent action decisions, affecting the continuity and stability of the operating condition response. Summary of the Invention

[0004] The purpose of this invention is to address the shortcomings of existing technologies by proposing a digital twin monitoring system for drilling and well workover equipment.

[0005] To achieve the above objectives, the present invention adopts the following technical solution: a digital twin monitoring system for drilling and workover equipment includes:

[0006] The deposition path reconstruction module calls back the records of cuttings particles and drilling depth in the digital twin monitoring, applies pressure to measure radial deformation, maps the return time point to the depth position according to the fluid flow path, merges the deformation trajectory according to the drilling depth interval, reconstructs the dynamic distribution map of the bottom hole deposition path, and generates a return deposition deformation path map.

[0007] The trend segment identification module locates the dense area of ​​the trajectory in the return deposition deformation path map, identifies the corresponding drilling depth number, extracts the drilling speed sequence, compares the amplitude of the dense segment with the edge segment, judges the synchronous trend, divides the drilling depth number segment, and forms a set of spatial trend evolution segments.

[0008] The differential pressure offset positioning module retrieves the pressure data of the drilling depth section involved in the spatial trend evolution segment set, calculates the lateral adjacent difference ratio, and locates the drilling depth points with opposite change directions and offsets based on the difference in the direction of the interlayer difference, thus obtaining a multi-segment differential pressure offset point group.

[0009] The oscillation linkage analysis module combines the oscillation records of the multi-segment differential pressure offset point group to extract the changes in the drill string's axial and torsional amplitudes and the corresponding drilling speeds, screens the consistency between the amplitude and the drilling speed direction, determines whether they decrease and expand synchronously, merges the amplitude types, and generates an oscillation linkage response chain group.

[0010] As a further aspect of the present invention, the back-deposition deformation path map includes cuttings back-deposition time-series mapping points, particle radial deformation data, and sedimentary trajectory distribution within the drilling depth interval; the spatial trend evolution segment set includes drilling depth numbers for densely spaced trajectory segments, drilling rate amplitude trend types, and continuous segment number identifiers; the multi-segment pressure differential offset point group includes interlayer pressure differential amplitude anomaly points, drilling depth direction abrupt change points, and pressure differential offset concentration areas; and the oscillation linkage response chain group includes axial wave amplitude variation types, torsional wave amplitude variation types, and drilling rate and drilling pressure linkage modes.

[0011] As a further aspect of the present invention, the deposition path reconstruction module includes:

[0012] The cuttings collection and identification submodule acquires the cuttings particles collected during the return process, extracts the return time sequence and drilling depth records, binds the particle number with the corresponding drilling depth, and organizes them into a data group consisting of particle number, return time and drilling depth to generate particle return depth data.

[0013] The path location mapping submodule, based on the particle return depth data, calls the fluid channel path record, matches the depth position according to the return time, matches the depth coordinates of the particle in the drilling structure, organizes them into a mapping set of particle number and depth position, and generates depth path mapping data.

[0014] The deposition trajectory construction submodule applies pressure to the particle surface and records the corresponding radial deformation value based on the depth path mapping data. It merges particles deformed in the same direction according to the drilling depth interval, summarizes the deformation trajectories of the interval to construct a spatial distribution map, and obtains the return deposition deformation path map.

[0015] As a further aspect of the present invention, the trend segment identification module includes:

[0016] The trajectory dense positioning submodule obtains the densely distributed areas of the trajectory in the return deposition deformation path map, identifies the corresponding drilling depth number, extracts the drilling speed time series at the number, and combines the drilling depth and drilling speed in time order to generate a dense segment drilling speed sequence.

[0017] The amplitude direction determination submodule extracts the drilling speed change data of the dense segment and edge segment positions based on the dense segment drilling speed sequence, calculates the drilling speed amplitude rate, determines whether the amplitude direction is consistent, calculates the amplitude deviation between segments, and marks whether they are synchronized to obtain the amplitude direction consistency mark.

[0018] The trend segmentation construction submodule, based on the amplitude direction consistency marker, clusters the drilling depth numbers with the same adjacent marker state into continuous segments, arranges the numbers within the segments in chronological order, establishes a combination list of numbers and trend types, and obtains a set of spatial trend evolution segments.

[0019] As a further aspect of the present invention, the differential pressure offset positioning module includes:

[0020] The differential pressure extraction submodule acquires the pressure acquisition records of the drilling depth section covered by the spatial trend evolution segment set on the time axis. Based on the stratification position from the wellhead to the bottom of the well, it calls the stratification structure division parameters, extracts the pressure data in the continuous time period synchronously according to the stratification interval, and classifies the pressure value of each layer into the time horizontal sequence according to the sampling interval to obtain the stratified pressure sequence dataset.

[0021] The amplitude calculation submodule calculates the pressure difference between the current sampling point and the adjacent sampling point based on the layered pressure sequence dataset, establishes a difference sequence, extracts the amplitude change rate between consecutive points in the difference sequence by layer, calculates the pressure change ratio of the point in the corresponding layer segment, compares the relative differences in amplitude changes between layers, and obtains the interlayer pressure amplitude difference value.

[0022] The drilling depth point identification submodule identifies the direction of amplitude change of adjacent points between layers based on the interlayer pressure amplitude difference value, determines whether there are drilling depth points with opposite directions or significant offsets in the trend of difference change, and obtains a group of multiple pressure difference offset points.

[0023] As a further aspect of the present invention, the oscillation linkage analysis module includes:

[0024] The oscillation data extraction submodule obtains the drill string oscillation records within the corresponding time period of the multi-segment differential pressure offset point group, synchronously retrieves the drilling speed sequence within the corresponding time window, extracts the drill string axial amplitude, torsional amplitude and drilling speed value at the time point, constructs the joint change sequence of amplitude and drilling speed in chronological order, and generates the oscillation drilling speed joint sequence.

[0025] The consistency screening submodule extracts the difference sequence between the amplitude change direction and the drilling speed change direction based on the oscillation drilling speed joint sequence, determines whether the two change directions are the same within a time period, and marks them as synchronous expansion and synchronous decline states. It then classifies and screens all time windows to obtain a set of synchronous markers for the oscillation speed direction.

[0026] The linkage merging generation submodule, based on the vibration velocity direction synchronization mark set, categorizes the amplitude change, drilling speed change, and drilling pressure change values ​​within the corresponding time period of the synchronization mark into the same type of mark group, summarizes and merges them according to the oscillation direction, constructs a linkage linked list of the three changes in drilling pressure, drilling speed, and amplitude, and obtains the oscillation linkage response chain group.

[0027] As a further aspect of the present invention, the system also includes a joint control sequence generation module:

[0028] The joint control sequence generation module extracts the drilling depth and oscillation direction from the oscillation linkage response chain group, combines the deposition trend, pressure difference trend and trigger point information, sorts and filters priority groups, matches action instructions, writes them into the execution queue, and obtains the joint control operation execution sequence.

[0029] The joint control operation execution sequence includes the trigger node drilling depth number, the corresponding action instruction set, and the time series sorting result.

[0030] As a further aspect of the present invention, the joint control sequence generation module includes:

[0031] The trigger information combination submodule retrieves the drilling depth and oscillation direction information listed in the oscillation linkage response chain group, extracts the deposition trend type and pressure difference change trend corresponding to the continuous trigger points of drill bit action, and constructs a trigger structure sequence according to the time sequence and drilling depth sequence to generate a joint control trigger information set.

[0032] The priority group filtering submodule extracts the trigger frequency and the degree of concentration of the three types of parameter amplitudes in the combination based on the joint control trigger information set. Combinations with high frequency and concentrated amplitude are sorted and marked as high priority groups. Combinations with trigger frequency lower than the set number threshold are removed to obtain the joint control priority structure group.

[0033] The instruction queue writing submodule matches the executable action type corresponding to the trigger structure according to the joint control priority structure group, extracts the corresponding action instruction group and arranges them in order of trigger time, summarizes all high priority group corresponding instructions and writes them into the control queue structure to obtain the joint control operation execution sequence.

[0034] Compared with the prior art, the advantages and positive effects of the present invention are as follows:

[0035] In this invention, by constructing the correspondence between cuttings return paths and drilling depth time sequence, and integrating particle radial deformation and fluid flow channel positioning information, a spatial mapping map of depositional trajectories is formed. Combined with the drilling rate amplitude trend of dense trajectory sections, continuous evolution sections are extracted and a trend distribution set is constructed. Based on the pressure sequence difference amplitude change, inter-layer abnormal points are identified. Furthermore, the consistency relationship between drill string oscillation amplitude and drilling rate change direction is superimposed, and correlated linkage feature groups are screened. Key nodes are extracted according to trigger frequency and amplitude concentration, and corresponding operation instructions are generated to drive multi-parameter collaborative identification and intelligent generation of drilling and workover control paths. Attached Figure Description

[0036] Figure 1 This is a system flowchart of the present invention;

[0037] Figure 2 This is a flowchart of the deposition path reconstruction module of the present invention;

[0038] Figure 3 This is a flowchart of the trend segment identification module of the present invention;

[0039] Figure 4 This is a flowchart of the differential pressure offset positioning module of the present invention;

[0040] Figure 5 This is a flowchart of the oscillation linkage analysis module of the present invention;

[0041] Figure 6 This is a flowchart of the joint control sequence generation module of the present invention. Detailed Implementation

[0042] To make the objectives, technical solutions, and advantages of this invention clearer, the invention will be further described in detail below with reference to the accompanying drawings and embodiments. It should be understood that the specific embodiments described herein are merely illustrative and not intended to limit the invention.

[0043] In the description of this invention, it should be understood that the terms "length," "width," "upper," "lower," "front," "rear," "left," "right," "vertical," "horizontal," "top," "bottom," "inner," and "outer," etc., indicating orientation or positional relationships, are based on the orientation or positional relationships shown in the accompanying drawings and are only for the convenience of describing the invention and simplifying the description, and do not indicate or imply that the device or element referred to must have a specific orientation, or be constructed and operated in a specific orientation, and therefore should not be construed as a limitation of the invention. Furthermore, in the description of this invention, "a plurality of" means two or more, unless otherwise explicitly specified.

[0044] Please see Figure 1 A digital twin monitoring system for drilling and workover equipment includes:

[0045] The deposition path reconstruction module retrieves rock cuttings collected in the return process of the digital twin monitoring of the drilling and workover equipment, extracts the record corresponding to the rock cuttings return time sequence and drilling depth, applies pressure to the particle surface step by step and simultaneously measures the radial deformation value, calls the path record in the fluid flow channel to map the return time point of the particles to the depth position of the drilling structure, merges the trajectories of particles deformed in the same direction according to the drilling depth interval, reconstructs the dynamic distribution map of the deposition path in the bottom hole space in the virtual environment, and generates a return deposition deformation path map.

[0046] The trend segment identification module locates the densely distributed areas of the trajectory in the return sediment deformation path map, identifies the corresponding drilling depth number of the area and extracts the drilling rate change sequence on the time axis, compares the average amplitude rate of the sequence in the dense segment with the edge segment, determines whether the drilling rate has a synchronous trend with the sedimentation change based on the amplitude direction, divides the drilling depth number into multiple continuous segments according to the trend type, and obtains the spatial trend evolution segment set.

[0047] The differential pressure offset positioning module retrieves the pressure acquisition records of the drilling depth section covered by the spatial trend evolution segment set on the time axis, synchronously extracts the pressure data within a continuous time period according to the layer position from wellhead to bottom of well, and calculates the amplitude of adjacent difference after classifying the pressure values ​​into the horizontal sequence according to the sampling interval. Based on the difference in the direction of amplitude change between layers, the drilling depth points with opposite change direction or obvious offset are located, and multiple differential pressure offset point groups are obtained.

[0048] The oscillation linkage analysis module combines the drill string oscillation records of the corresponding time period of the multi-segment differential pressure offset point group, extracts the changes in the axial and torsional amplitude of the drill string within the time period, and simultaneously retrieves the corresponding drilling speed sequence. Within the same time window, it screens the consistency between the amplitude change direction and the drilling speed change direction, determines whether the two show a state of common decline or expansion, and merges the amplitude, drilling speed, and drilling pressure change types according to the oscillation direction to generate an oscillation linkage response chain group.

[0049] The joint control sequence generation module retrieves the drilling depth and oscillation direction information listed in the oscillation linkage response chain group, extracts the deposition trend type and differential pressure change trend corresponding to the continuous trigger points of the drill bit action, sorts the three types of information according to the time sequence and drilling depth order, filters and arranges priority groups according to the trigger frequency and amplitude concentration, matches the executable action instruction group based on the trigger node type and writes it into the execution queue to obtain the joint control operation execution sequence.

[0050] The return sedimentary deformation path map includes cuttings return time-series mapping points, grain radial deformation data, and sedimentary trajectory distribution within the drilling depth interval. The spatial trend evolution segment set includes drilling depth numbers for densely trajectory segments, drilling rate amplitude trend types, and continuous segment number identifiers. The multi-segment pressure difference offset point group includes inter-layer pressure difference ratio anomalous points, drilling depth direction abrupt change points, and pressure difference offset concentration areas. The oscillation linkage response chain group includes axial wave amplitude variation types, torsional wave amplitude variation types, and drilling rate and drilling pressure linkage modes. The joint control operation execution sequence includes trigger node drilling depth numbers, corresponding action instruction sets, and time series sorting results.

[0051] Please see Figure 2 The deposition path reconstruction module includes:

[0052] The cuttings collection and identification submodule acquires the cuttings particles collected during the return process, extracts the return time sequence and drilling depth records, binds the particle number with the corresponding drilling depth, and organizes them into a data group consisting of particle number, return time and drilling depth to generate particle return depth data.

[0053] During the drilling return process, particle collection is performed. The sampling device is located at the upper end of the drilling fluid return channel. It automatically opens the sampling valve every 10 seconds for 0.5 seconds, capturing approximately 3 to 5 particles each time. Each particle is immediately transferred to the marking and processing unit and assigned a serial number, such as 0001, 0002, 0003, etc. Simultaneously, the drilling operating system has a high-precision drilling depth recording module that records the current drilling depth of the drill bit every 0.1 seconds with a depth accuracy of 0.1 mm. Sampling and drilling depth recording are synchronized via the system's master clock. For each sampled particle, the system searches for the data row in the depth record data closest to its time point at the time of its return acquisition. The matching method is a window sliding search, i.e., a time matching threshold of ±0.3 seconds is set. If a sampled particle is captured at the 100th second, the system allows matching drilling depth data within the time range of 99.7 seconds to 100.3 seconds. If multiple particles are captured within this time range... For depth records, the depth value corresponding to the closest time point is taken as the binding depth of the particle. For example, if there are three record points in this time period, namely the 99.8 second, 100.0 second, and 100.2 second, with corresponding depth values ​​of 3050.2 mm, 3050.5 mm, and 3051.0 mm, then 3050.5 mm is selected as the result depth. If there is no valid record within the search time range, the particle data is marked as "unmatched" and does not participate in subsequent processing. The system found in a large amount of data that 92% of the deviations in the synchronization between the return sampling time and the drilling depth recording time are within ±0.25 seconds, with a limit error of 0.32 seconds. Therefore, the final time matching threshold is set to ±0.3 seconds. All successfully matched data are finally formed into a triplet, namely the particle number, the return time point number, and the corresponding drilling depth value, such as 0003-100 seconds-3050.5 mm, forming a cuttings return depth dataset for use by subsequent modules.

[0054] The path location mapping submodule, based on particle return depth data, calls the fluid channel path record, matches the depth position according to the return time, and matches the depth coordinates of the particles in the drilling structure, organizes them into a mapping set of particle number and depth position, and generates depth path mapping data.

[0055] The system retrieves the particle number and corresponding drilling depth data from the previous stage, then reads the liquid path record. This record uses a built-in fluid tracking identifier to deploy a set of sensor modules every 100 mm in the return channel, collecting the current liquid position and time point correspondence every second to generate a structured channel path table. The actual position of each particle in the channel at the return time point needs to be confirmed by matching the liquid flow path log. The time matching threshold is set to ±1 second. If the return time of particle number 0003 is 100 seconds, the system will search for data between 99 and 101 seconds in the path log. Assuming two records are found within this range, 99.5 seconds corresponds to a depth of 1250 mm, and 100.5 seconds corresponds to a depth of 1220 mm. The system will determine the proximity of the time difference between the two points to the particle's return time point. In this example, the distance is 0.5 seconds. The system prioritizes the earlier time point, so 99.5 seconds is chosen. A 5-second interval corresponds to a depth of 1250 mm, establishing a mapping relationship of 0003→1250 mm. If only one matching time point exists, its corresponding depth is directly used. This threshold setting references the liquid flow velocity range of 0.1 to 0.2 m / s in the channel, with a maximum fluctuation of approximately 100 mm / s. Therefore, a time error within 1 second will not cause a displacement error exceeding one sensor segment (100 mm), thus ensuring the reliability of the depth position. If there is no record or abnormal data within ±1 second, the particle is marked as "path missing". In batch data processing, if particle numbers 0001, 0002, 0003, and 0004 correspond to drilling depths of 3100, 3080, 3050, and 3010 mm respectively, their path positions after system matching are 1340, 1300, 1250, and 1190 mm respectively. All numbers and depth coordinates constitute a mapping set, providing an accurate positional basis for the deposition trajectory construction submodule.

[0056] The sedimentation trajectory construction submodule applies pressure to the particle surface and records the corresponding radial deformation value based on the depth path mapping data. It merges particles deformed in the same direction according to the drilling depth interval, summarizes the deformation trajectories of the interval to construct a spatial distribution map, and obtains the return sedimentation deformation path map.

[0057] After reading the particle number and path depth of all particles, the particle number is associated with its surface deformation record, which comes from high-precision radial dimension detection of each particle. During the detection process, after all particles are recovered to the ground, they are first processed by an image screening device to remove mud, and then sent to a laser measuring station to measure their shortest and longest radial distances, and compared with standard dimensions to determine whether compression deformation has occurred. For example, the original diameter of particle 0003 is 6.00 mm, and after measurement it is 5.92 mm, so the compression deformation value is 0.08 mm. The system sets a significant threshold for radial deformation of 0.05 mm. This threshold is based on the deformation statistics of 500 particle samples, where the maximum deformation of the indeformed sample is 0.04 mm. Therefore, deformation greater than 0.05 mm can be considered as actual deformation caused by external compressive stress. All deformed particles are grouped according to their depth position. The system uses a depth interval of 200 mm, such as 1000–1200 mm. Within the same sedimentary range (e.g., 1200–1400 mm), if two or more particles exist with compression deformation in the same direction and a difference of less than 0.03 mm, they are classified into the same sedimentary unit. Their average deformation value is recorded as an indicator of sedimentary deformation within the range. For example, in the 1200–1400 mm range, three particles have compression values ​​of 0.06, 0.07, and 0.08 mm, with an average of 0.07 mm. If the difference between particles within a range exceeds 0.03 mm, they are not merged and are recorded separately. This merging error threshold is derived from the discrete range of compression values ​​after pressure testing in a 6.0 mm sample, where the maximum standard deviation is 0.028 mm; therefore, 0.03 mm is used as the judgment limit. Finally, the sedimentary compression values ​​for each range are output as trajectory data points, for example (range 1200–1400 mm, compression deformation value 0.07 mm). Multiple trajectory points constitute a spatial sedimentary map, used to reveal the trend of structural sedimentary changes.

[0058] Please see Figure 3 The trend segment identification module includes:

[0059] The trajectory dense positioning submodule obtains the densely distributed areas of trajectory in the return deposition deformation path map, identifies the corresponding drilling depth number, extracts the drilling speed time series at the number, and combines the drilling depth and drilling speed in time order to generate the dense segment drilling speed sequence.

[0060] To obtain densely distributed areas of trajectory distribution in the return deposition deformation path map, the path map is first divided into two-dimensional grid partitions. Vertically, the drilling depth is divided into segments of 200 mm each. Horizontally, a 1:1 grid is used based on the average abscissa of the trajectory points. The number of trajectory points in each segment is counted. After calculating the average trajectory density across all segments, the system sets a density identification threshold of 1.5 times the average density value. If the average number of trajectory points across the 80 segments in the entire path map is 12, then the density judgment threshold is 18 or more trajectory points. This threshold is derived from previous analysis showing that the trajectory point density in densely active drilling segments often exceeds the average by 1.3 to 1.6 times; therefore, 1.5 times is ultimately set as a reasonable threshold. For example, if 21 trajectory points are counted in segment 14 (drilling depth 2600 to 2800 mm) and 22 in segment 15, the system merges these two into a single dense area for further extraction. The system generates a set of corresponding drilling depth numbers, for example, numbers A101 to A105. Then, it calls the drilling speed time series corresponding to numbers A101 to A105. The drilling speed record is sampled once per second, and each sequence contains 30 seconds of continuous data. For example, the drilling speed corresponding to A101 is [3.2, 3.1, 3.0, 3.3, 3.2] m / min, and A102 is [3.1, 3.2, 3.1, 3.0, 3.1] m / min, and so on. The numbers and drilling speed sequences are matched one-to-one to form a set of dense segment drilling speed sequences. The data structure is constructed in the form of "number → drilling speed sequence", forming the basic data for the original drilling speed time series analysis, such as A101 → [3.2, 3.1, 3.0, 3.3, 3.2], A102 → [3.1, 3.2, 3.1, 3.0, 3.1], and finally generating the dense segment drilling speed sequence.

[0061] The amplitude direction determination submodule extracts the drilling speed change data of the densely packed and edge segments based on the drilling speed sequence, calculates the drilling speed amplitude rate of each segment, and determines whether the amplitude direction is consistent, using the following formula: ;

[0062] The calculation obtains the amplitude deviation between segments, and marks whether they are synchronized based on this, thus obtaining the amplitude direction consistency mark;

[0063] in, This represents the deviation of the amplitude between segments. Representing the dense segment Drilling speed at all times Represents the edge segment Drilling speed at all times Indicates the first Drill depth difference This indicates the magnitude of the pressure change at that point. Factor indicating the direction of change in depositional trend. Indicates the number of sample points.

[0064] After receiving the drilling speed sequence of the dense section, the amplitude direction determination submodule first extracts the edge segment number for each number. The rule is: take two non-overlapping numbers before and after the dense section as the edge segment. For example, if the dense section numbers are A101 to A105, then the edge segment numbers are B099, B100, B106, and B107. The system reads the drilling speed data of these numbers and constructs the edge segment drilling speed sequence, such as B100 → [2.8, 2.7, 2.6], B106 → [2.9, 2.8, 2.7]. Subsequently, the system establishes a one-to-one comparison group for the dense section and the corresponding edge segment according to the number order, such as A101 corresponding to B100, A102 corresponding to B106. In each comparison group, the system extracts the following parameters:

[0065] : The value at each moment in the drilling rate sequence of the dense section, such as A101 being [3.2, 3.1, 3.0];

[0066] Drilling speed values ​​for edge sections, such as [2.9, 2.8, 2.6] for B100;

[0067] The drilling depth difference is calculated based on the depth interval between the numbers. If the depth of A101 is 2600 mm and that of B100 is 2540 mm, then the difference is 60 mm.

[0068] Pressure change amplitude, taken from formation pressure monitoring data, assumed to be 0.6 MPa here;

[0069] : Depositional direction factor, which is quantified by the system according to the direction of depositional deformation: +1 for positive pressure, -1 for negative pressure, and 0 for stationary conditions, such as +1 for this segment;

[0070] Number of sample points, which is 3 here;

[0071] Substituting the actual values, the calculation is as follows:

[0072] ;

[0073] ;

[0074] ;

[0075] The molecule obtained is the total drilling rate difference: ;

[0076] Denominator term:

[0077] (Take the average or uniform value);

[0078] Adding them together, we get: The square root is approximately (Because all three points are +1);

[0079] The total denominator is: ;

[0080] The final result is: ;

[0081] The comparison judgment threshold is set to 0.04 (this value is based on the statistical analysis of the amplitude synchronization section ΔT range in the previous samples, with 95% of the data concentrated between 0.015 and 0.035, and the upper limit is set to 0.04). If the current result is less than this threshold, the system marks A101 and its edge segment amplitude direction as "consistent". If ΔT is greater than 0.04, it is judged as "inconsistent". Finally, the deviation calculation and consistency marking of all numbers are completed one by one, such as A101 → consistent, A102 → consistent, A103 → inconsistent, etc.

[0082] The trend segmentation construction submodule is based on the consistency marker of the amplitude direction. It clusters the drilling depth numbers with the same adjacent marker status into continuous segments, arranges the numbers in the segment in chronological order, establishes a combination list of numbers and trend types, and obtains the set of spatial trend evolution segments.

[0083] After obtaining the consistency markers for the amplitude direction, the trend segmentation construction submodule begins to perform continuous number clustering. The system scans the consistency markers in numerical order. For example, if the number sequence is A101→consistent, A102→consistent, A103→inconsistent, A104→inconsistent, A105→consistent, the system searches backward from A101, grouping consecutive numbers with the same marker status into a trend segment, forming the first segment [A101, A102], marked as consistent. When the marker status of A103 changes to inconsistent, the system starts a new segment [A103, A104]. If the next number A105 returns to consistent, the third segment [A105] is formed. The system sets a minimum threshold of 2 for the number of trend segments. If a segment contains only 1 number (e.g., A105), the system will not perform a clustering operation. If a segment is identified as an "isolated segment," the system processes it according to the following rules: if it is in the same state as the preceding and following segments, it is merged into the preceding segment; if it is different, it is temporarily retained and recorded as a sudden change segment. This threshold is determined based on the drilling depth spacing in the drilling sequence being no less than 200 mm and the shortest length of the trend segment being no less than 400 mm. The numbers within each segment are then rearranged in chronological order to generate a segment number list, such as segment 1: [A101, A102], segment 2: [A103, A104], segment 3: [A105], corresponding to the states of consistent, inconsistent, and consistent, respectively. The final output is a combination set of consecutive numbered segments and trend states, i.e., segment 1 → consistent, segment 2 → inconsistent, segment 3 → consistent, constituting a spatial trend evolution segment set, which is used as the basic data input for subsequent rock strata stability structure analysis.

[0084] Please see Figure 4 The differential pressure offset positioning module includes:

[0085] The differential pressure extraction submodule acquires the pressure acquisition records of the drilling depth section covered by the spatial trend evolution segment set on the time axis. Based on the stratification position from the wellhead to the bottom of the well, it calls the stratification structure division parameters, extracts the pressure data in the continuous time period synchronously according to the stratification interval, and classifies the pressure value of each layer into the time horizontal sequence according to the sampling interval to obtain the stratified pressure sequence dataset.

[0086] After receiving the set of spatial trend evolution segments, the system first obtains the drilling depth range covered by each trend segment and establishes a drilling depth-time mapping index. All covered segments are then divided into multiple continuous layered regions according to drilling depth, with each layer having a fixed drilling depth span of 200 mm. For example, if the starting and ending drilling depths of a trend segment are 1500 mm to 1900 mm, it is divided into two layers: L1 (1500–1700 mm) and L2 (1700–1900 mm). The system then calls the layered configuration parameters in the wellbore structure to confirm the number and placement depth of the pressure sensors embedded in each layer, and determines that the pressure sampling frequency is recorded once every 5 seconds. After obtaining the sensor pressure recording files, the pressure values ​​on the corresponding time axis are categorized according to the drilling depth segments. At each 5-second time point, the pressure value sequences for the L1 and L2 segments are obtained respectively. For example, in the first time period, the pressure collected in the L1 segment is 10.2 MPa, and in the L2 segment it is 10.5 MPa. MPa; the collected values ​​in the second time period were 10.4 MPa and 10.3 MPa, and in the third time period were 10.1 MPa and 10.6 MPa; the system binds each pressure value to its corresponding layer horizontally according to the sampling interval of 5 seconds. For example, the sequence of the L1 layer at the three time points is [10.2, 10.4, 10.1] MPa, and the L2 layer is [10.5, 10.3, 10.6] MPa; the system then verifies the continuity of the pressure data and checks for anomalies. If the pressure difference between adjacent sampling points exceeds 1.0 MPa, it is recorded as a "distortion point". This threshold is set from the statistical analysis of the normal range of formation pressure gradient changes. Its maximum instantaneous jump amplitude does not exceed 0.85 MPa, so 1.0 MPa is used as the allowable upper limit; all valid pressure points are stored in the layered pressure sequence dataset, with the structure of layer number bound to the corresponding time series, for use in the next amplitude calculation module.

[0087] The amplitude calculation submodule, based on a hierarchical pressure sequence dataset, calculates the pressure difference between the current sampling point and its adjacent sampling points, establishes a difference sequence, and extracts the rate of change of amplitude between consecutive points in the difference sequence layer by layer, using the formula: ;

[0088] The pressure change ratio of the point in the corresponding layer is calculated, and the relative difference in pressure amplitude between layers is compared to obtain the interlayer pressure amplitude difference value; among which, Indicates the first Layer Pressure change ratio at sampling points For the first Layer Pressure value at sampling point The pressure values ​​are from adjacent sampling points. These are the pressure values ​​at corresponding points in adjacent layers. Indicates the first The set of all sampling points in the layer. This represents the number of points in the set. For amplitude adjustment constant, For the first The drilling depth of the layer, For the first Layer The sampling time interval of the points.

[0089] After reading the hierarchical pressure sequence dataset, the amplitude calculation submodule calculates the rate of pressure change for each sampling point in each layer, based on the formula: ;

[0090] Let's take the second sampling point of layer L1 as an example to illustrate the actual calculation:

[0091] This is the pressure at the second sampling point of layer L1;

[0092] , which is the adjacent previous time point;

[0093] The adjacent layer is L2, and the corresponding point pressure value is ;

[0094] All sampled values ​​of the current layer The set is The score is 3;

[0095] The drilling depth was 1500 mm, and the sampling interval was 5 seconds.

[0096] Amplitude adjustment constant The value is determined by the sensor's minimum response error (maximum error is ±0.05MPa, taken as a positive value).

[0097] Step 1, Calculate the molecule:

[0098] ;

[0099] Step 2, calculate the denominator of the square root term:

[0100] ;

[0101] The results for the first part are as follows:

[0102] ;

[0103] Step 3: The average difference between the current sampling point and all sampling points is:

[0104] ;

[0105] Step four, divide the drilling depth by the sampling interval: ;

[0106] Final synthesis: ;

[0107] Because this value is significantly distorted, the system normalizes the drilling depth. If the maximum drilling depth is 2000 mm, the normalized drilling depth is 0.75. The last term is then recalculated as follows: ;

[0108] The new value is now:

[0109] ;

[0110] If the value is less than the upper limit threshold of 1.0 for amplitude difference judgment, the pressure change ratio at the current sampling point is judged to be "normal". If the value is greater than 1.5, the system marks it as an "abnormal point" and enters the pressure difference offset judgment process.

[0111] The drilling depth point identification submodule identifies the direction of amplitude change of adjacent points between layers based on the difference in pressure amplitude between layers, determines whether there are drilling depth points with opposite directions or significant offsets in the trend of difference change, and obtains multiple pressure difference offset point groups.

[0112] Based on the pressure change ratio values ​​obtained in the previous step, the system first constructs a record of the change direction between two adjacent sampling points within each layer. The direction is determined by the sign of the ratio change: if the latter is larger than the former, it is recorded as "positive"; otherwise, it is "negative"; if they are equal, it is "stable". For example, if the ratio values ​​of the three points in layer L1 are 0.52, 0.62, and 0.45, then the first group is "positive" and the second group is "negative". Next, the system extracts the ratio difference sequence between corresponding points across layers and calculates the magnitude of the difference change between adjacent points. If the change value between two adjacent points exceeds a set threshold of 0.3 MPa, it is recorded as a "sudden change in magnitude". This threshold is set based on the statistical results of previous well test experiments. In the experiment, the maximum normal inter-layer difference does not exceed 0.28 MPa. The maximum value is increased by 10% to obtain the result. By comparing the directional trend, if the directions of three consecutive points are "positive-negative-positive" or "negative-positive-negative", the system marks them as "directional fluctuation points" and records the points where amplitude changes and directional fluctuations are superimposed as "pressure difference offset points". For example, in the L1 layer, the second sampling point is 0.62, the third point is 0.45, and the adjacent L2 layer points are 0.75 and 0.90. The cross-layer difference is 0.13 and 0.45. The latter exceeds the threshold, and the point happens to reverse direction. Then the drilling depth point (numbered B107) is recorded as a pressure difference offset point. Finally, the system categorizes all numbers that meet the "directional change + amplitude change" condition into multi-segment pressure difference offset point groups, such as [B107, B112, B116], as anomaly identification results.

[0113] Please see Figure 5 The oscillation linkage analysis module includes:

[0114] The oscillation data extraction submodule obtains the drill string oscillation records within the time period corresponding to multiple differential pressure offset point groups, synchronously retrieves the drilling speed sequence within the corresponding time window, extracts the drill string axial amplitude, torsional amplitude and drilling speed value at the time point, constructs the joint change sequence of amplitude and drilling speed in chronological order, and generates the oscillation drilling speed joint sequence.

[0115] After obtaining the time periods corresponding to multiple differential pressure offset point groups, the system first extracts the effective time range corresponding to each offset point number. For example, the time period for the oscillation anomaly point corresponding to number B107 is from 0 seconds to 20 seconds. The system retrieves the drill string oscillation data within this time period from the drill string dynamic monitoring system. The data mainly includes two dimensions: the axial amplitude and torsional amplitude of the drill string. The axial amplitude represents the displacement amplitude of the drill string in the longitudinal direction, in millimeters, and the torsional amplitude is the angular change amplitude of the drill string in the rotation direction, in degrees. In addition, the system synchronously calls the drilling speed sampling data within this time period. The sampling frequency of the drilling speed data is set to once every 5 seconds, consistent with the oscillation sampling. The system constructs a joint sequence of the three sampling values ​​with the time point as the index. For example, at 0 seconds, the axial amplitude is 1.2 mm, the torsional amplitude is 2.0 degrees, and the drilling speed is 1.2 mm. The drilling speed is 3.0 meters per minute. At 5 seconds, the speeds are 1.5 mm, 2.5 degrees, and 3.2 meters per minute, respectively. At 10 seconds, the speeds are 1.3 mm, 2.2 degrees, and 3.4 meters per minute, and so on, up to the 20-second sampling point. The system extracts a total of 5 sets of time point samples. Each set of data is constructed into a triplet data structure and sorted by time to obtain a complete time series. The system further verifies whether each time point has three data items simultaneously. If any data item is missing or the sampling time point interval exceeds 5.5 seconds, the time point is marked as "incomplete data" and removed, and is not included in the joint sequence. Finally, the oscillation amplitude and drilling speed of all valid time points are merged to construct an oscillation drilling speed joint sequence. The length of this sequence is determined by the number of consecutive complete sampling points. Each segment of the sequence is bound to the corresponding differential pressure offset point number as a unique dataset.

[0116] The consistency screening submodule is based on the oscillating drilling speed joint sequence. It extracts the difference sequence between the amplitude change direction and the drilling speed change direction, determines whether the two change directions are the same within a time period, and marks them as synchronous expansion and synchronous decline states. It classifies and screens all time windows to obtain the oscillating speed direction synchronization mark set.

[0117] The main purpose of processing the oscillation drilling rate combined sequence is to identify the correspondence between the amplitude change trend and the drilling rate change trend. The system first extracts the axial amplitude change direction and drilling rate change direction between adjacent time points in the combined sequence. The direction is defined as follows: if the value of the later point is greater than the value of the previous point, it is "increasing"; if it is less, it is "decreasing"; if it is equal, it is "stable". The system then records the combination of oscillation direction and drilling rate direction for each pair of consecutive time points in chronological order. For example, in the time period from 0 seconds to 5 seconds, the axial amplitude increases from 1.2 mm to 1.5 mm, the torsional amplitude increases from 2.0 degrees to 2.5 degrees, and the drilling rate increases from 3.0 m / min to 3.2 m / min. Therefore, all three changes are in the "increasing" direction, and this segment is recorded as "synchronous expansion". Another example is from 5 seconds to 10 seconds, where the axial amplitude decreases to 1.3 mm, but the drilling rate increases to 3.4 m / min. The oscillation and drilling rate directions are inconsistent, and the system... Marked as "asynchronous", the system defaults to a "synchronous segment" if at least two of the three indicators are in the same direction, otherwise it is a "asynchronous segment". The synchronous segment is further divided into "synchronous expansion" and "synchronous decline", which correspond to the three indicators rising or falling together. If the direction is marked as rising + falling + rising or falling + rising + falling, it is judged as a "crossing segment". If the crossing segment appears more than twice in the sequence corresponding to an offset point, the system marks the entire time period corresponding to the offset point as an "unstable segment". The synchronization recognition threshold in this rule comes from the statistics of 200 sets of drilling process data. In more than 90% of the stable segments, the three change directions are similar and the average number of different directions does not exceed 1. Therefore, the maximum number of different directions is set to 1 as the basis for synchronization judgment. Finally, the set of synchronous markers for the velocity direction corresponding to each offset point number is obtained by screening. For example: [synchronous expansion, asynchronous, synchronous decline, synchronous expansion].

[0118] The linkage merging generation submodule, based on the vibration velocity direction synchronization mark set, categorizes the amplitude change, drilling speed change, and drilling pressure change values ​​within the corresponding time period of the synchronization mark into the same type of mark group, summarizes and merges them according to the oscillation direction, constructs a linkage chain list of the three changes in drilling pressure, drilling speed, and amplitude, and obtains the oscillation linkage response chain group.

[0119] After acquiring the set of synchronous markers for vibration velocity direction, the amplitude change, drilling speed change, and drilling pressure change values ​​of the same marker type in each time period are grouped into a unified marker category. First, the system filters out the start and end times of all "synchronous expansion" time periods based on the time point markers. For example, the time periods from 0 to 5 seconds and from 15 to 20 seconds are considered "synchronous expansion." The system reads the change values ​​of each physical quantity and calculates the difference. For example, from 0 to 5 seconds, the axial amplitude increases from 1.2 mm to 1.5 mm, the torsional amplitude increases from 2.0 degrees to 2.5 degrees, and the drilling speed increases from 3.0 m / min to 3.2 m / min. Therefore, the changes in these three items for this period are +0.3 mm, +0.5 degrees, and +0.2 m / min, respectively. Similarly, the changes for the 15 to 20 second time period are +0.5 mm, +0.8 degrees, and +0.4 m / min. The system averages the physical change values ​​for each item in all segments with the same marker to obtain the linkage average value corresponding to the "synchronous expansion" marker: axial amplitude 0.4 mm, torsional amplitude... At a drilling speed of 0.3 m / min and a drilling angle of 0.65 degrees, the changes in drilling pressure, provided by the wellhead data acquisition system, are 5.2 kN and 4.8 kN respectively, with an average of 5.0 kN. This value is synchronously assigned to this group. The system uses the same processing method for the "synchronous descent" time period. If there are three or more time periods in a group, and the maximum change difference exceeds 50% of the average, then the group is marked as a "strong fluctuation group". The fluctuation identification threshold is set based on the statistical analysis of the standard deviation of each physical item in the oscillation dynamic. The average range within 95% of the interval is 0.45 times the average value. Therefore, the system uses 0.5 times as the strong fluctuation judgment standard. Finally, each synchronous marked group is organized into a linkage chain group with the following structure: [marker type, average axial amplitude change value, average torsional amplitude change value, average drilling speed change value, average drilling pressure change value], such as [synchronous extension, 0.4 mm, 0.65 degrees, 0.3 m / min, 5.0 kN], etc. Each linkage chain item corresponds to a type of oscillation response performance, which is used for subsequent linkage anomaly identification.

[0120] Please see Figure 6 The joint control sequence generation module includes:

[0121] The trigger information combination submodule retrieves the drilling depth and oscillation direction information listed in the oscillation linkage response chain group, extracts the deposition trend type and pressure difference change trend corresponding to the continuous trigger points of drill bit action, and constructs the trigger structure sequence according to the time sequence and drilling depth sequence to generate the joint control trigger information set.

[0122] After the trigger information combination submodule obtains the oscillation linkage response chain group, the system first reads the drilling depth number and oscillation direction identifier value corresponding to each record in the chain group in sequence. Then, it retrieves the sedimentary trend type of the area where the drilling depth number is located and the pressure difference change trend data provided by the wellbore pressure analysis module from the corresponding formation sedimentary structure model. Each number group is parsed to contain four items: drilling depth number, oscillation direction, sedimentary trend, and pressure difference change. The system judges whether the above three states can be combined into valid structural trigger information. If any item is "missing measurement" or "abnormal identifier", the group is marked as "untriggerable combination" and removed from the combination sequence. In the remaining valid combinations, each group number is arranged from small to large according to the drilling depth to form a set of structural trigger number sequences. For example, the three information items corresponding to the numbers D1500, D1600, D1700, D1800, and D1900 are "expansion-contraction-rise" in sequence. The system constructs a set of structural fields for each set of results, including "Decline-Expansion-Decline", "Expansion-Contraction-Rise", "Decline-Expansion-Decline", and "Expansion-Contraction-Rise". Each set can be independently combined to form a joint control trigger information unit. If the oscillation direction is opposite to the pressure difference trend, but the deposition trend is consistent with the oscillation direction, the combination is marked as a "trend conflict group". Because this situation has an inconsistent impact on structural stability in the previous oscillation response test, it cannot stably match the preset action. Therefore, the judgment rule is set to judge it as a conflict combination when "oscillation direction = deposition trend and pressure difference change direction ≠ oscillation direction". The setting logic comes from the fact that the probability of such inconsistent combinations causing anomalies exceeds 78% in the data sample of 42 wells. Therefore, they are uniformly filtered out. The final set of retained combinations is output as the joint control trigger information set. Each set of data consists of four items: drilling depth number + oscillation direction + deposition trend + pressure difference trend, which are used by subsequent modules for action decision matching.

[0123] The priority group filtering submodule extracts the trigger frequency and the degree of concentration of the three types of parameter amplitudes in the combination based on the joint control trigger information set. Combinations with high frequency and concentrated amplitude are sorted and marked as high priority groups. Combinations with trigger frequency lower than the set number threshold are removed to obtain the joint control priority structure group.

[0124] After reading the aforementioned joint control trigger information set, the priority group screening submodule extracts four numerical indicators for each combination: trigger frequency, amplitude variation, drilling speed variation, and drilling pressure variation. First, it performs preliminary screening based on trigger frequency. The system sets a frequency threshold of 3 times; that is, if a combination is recorded as a trigger point less than 3 times in the oscillation linkage chain group, it is determined to be a non-highly sensitive area and is removed. This threshold is based on the distribution range of trigger frequency in 370 linkage chains statistically analyzed by the drilling data platform, where combinations with a frequency exceeding 3 times account for 92% of the causes of abnormal actions. Therefore, 3 times is set as the validity segmentation standard. For the remaining combinations, the system comprehensively evaluates the amplitude variation, drilling speed variation, and drilling pressure variation of each group, setting the "concentration degree" as whether the three indicators simultaneously exceed 1.2 times their sample mean. The current sample mean is amplitude variation of 0.4 mm, drilling speed variation of 0.3 m / min, and drilling pressure variation of 0.6 kN, therefore the concentration boundary values ​​are 0.48 mm, 0.3 m / min, and 0.6 kN, respectively. For example, D1700 corresponds to three values ​​of 0.5 mm, 0.4 m / min, and 0.7 kN, two of which exceed the concentration threshold. Since not all of them exceed the threshold, the system marks them as "medium concentration". D1900 has three values ​​of 0.6 mm, 0.5 m / min, and 0.8 kN, all of which exceed the boundary value, so it is marked as "high concentration". The judgment rule is: if all values ​​are greater than the set value, it is "high concentration", any two values ​​are "medium concentration", and only one value is "low concentration". The system then performs priority judgment based on frequency + concentration. The highest priority is "frequency ≥ 3 and concentration = high concentration", followed by "frequency ≥ 3 and concentration = medium concentration", and the rest are in descending order. Finally, D1900 and D1700 are assigned to the high priority group. Others, such as D1600, are removed because the frequency is only 2, and D1800 is also removed because the concentration is only "low concentration". The list of high priority structure groups is output as the input source for subsequent instruction triggers.

[0125] The instruction queue writing submodule matches the executable action type corresponding to the trigger structure according to the joint control priority structure group, extracts the corresponding action instruction group and arranges them in order of trigger time, summarizes all high priority group corresponding instructions and writes them into the control queue structure to obtain the joint control operation execution sequence.

[0126] After the instruction queue writing submodule obtains the high-priority structure group, it first reads the oscillation direction, deposition trend, and differential pressure change markers in each numbered combination and matches them with the corresponding action type library. The system has an oscillation joint control action index table. Each combination structure is bound to one or more preset executable action types. For example, the action corresponding to "expanding oscillation + contraction trend + differential pressure increase" is "drill pressure maintenance + drill speed slow reduction + stabilization valve control", while the action corresponding to "descending oscillation + expanding trend + differential pressure decrease" is "drill pressure reduction + drill speed increase control + amplitude activation". The system calls up the action type according to the combination result and extracts the corresponding control instruction structure. Each control instruction consists of three items: "action type → parameter setting → module channel". For example, the action matched by D1900 is "continuous slow rotation", and the control parameters are... "Torque limit not greater than ±3%, drilling pressure maintained within ±0.2 kN error." The module channel is "torque controller + drilling pressure regulator." The instruction structure is written into the control instruction set in numerical order. The numbering rule is that the number takes precedence from the smallest to the largest drilling depth. If the numbers of the same layer are the same, they are arranged according to the oscillation amplitude, with the larger amplitude taking precedence. The system sets the drilling pressure adjustment error threshold to not exceed 0.3 kN. If it exceeds this threshold, the instruction is marked as "failed instruction" and the instruction structure is rewritten. After all instruction items are formatted, they form a complete control queue structure. The record structure is: [number → action name → control item → regulation parameter → hardware module channel]. Finally, a joint control operation execution sequence is formed for the drilling automation system to receive and execute. This execution sequence maintains a one-to-one correspondence with the structure group matching items for subsequent linkage response execution calls.

[0127] The above are merely preferred embodiments of the present invention and are not intended to limit the present invention in any other way. Any person skilled in the art may make changes or modifications to the above-disclosed technical content to create equivalent embodiments that can be applied to other fields. However, any simple modifications, equivalent changes, and modifications made to the above embodiments based on the technical essence of the present invention without departing from the scope of the present invention shall still fall within the protection scope of the present invention.

Claims

1. A digital twin monitoring system for drilling and workover equipment, characterized in that, The system includes: The deposition path reconstruction module calls back the records of cuttings particles and drilling depth in the digital twin monitoring, applies pressure to measure radial deformation, maps the return time point to the depth position according to the fluid flow path, merges the deformation trajectory according to the drilling depth interval, reconstructs the dynamic distribution map of the bottom hole deposition path, and generates a return deposition deformation path map. The trend segment identification module locates the dense area of ​​the trajectory in the return deposition deformation path map, identifies the corresponding drilling depth number, extracts the drilling speed sequence, compares the amplitude of the dense segment with the edge segment, judges the synchronous trend, divides the drilling depth number segment, and forms a set of spatial trend evolution segments. The differential pressure offset positioning module retrieves the pressure data of the drilling depth section involved in the spatial trend evolution segment set, calculates the lateral adjacent difference ratio, and locates the drilling depth points with opposite change directions and offsets based on the difference in the direction of the interlayer difference, thus obtaining a multi-segment differential pressure offset point group. The oscillation linkage analysis module combines the oscillation records of the multi-segment differential pressure offset point group to extract the changes in the drill string's axial and torsional amplitudes and the corresponding drilling speeds, screens the consistency between the amplitude and the drilling speed direction, determines whether they decrease and expand synchronously, merges the amplitude types, and generates an oscillation linkage response chain group.

2. The digital twin monitoring system for drilling and workover equipment according to claim 1, characterized in that, The back-deposition deformation path map includes cuttings back time-series mapping points, particle radial deformation data, and sedimentary trajectory distribution within the drilling depth range. The spatial trend evolution segment set includes drilling depth numbers for densely spaced trajectory segments, drilling rate amplitude trend types, and continuous segment number identifiers. The multi-segment pressure difference offset point group includes interlayer pressure difference ratio anomalous points, drilling depth direction abrupt change points, and pressure difference offset concentration areas. The oscillation linkage response chain group includes axial wave amplitude variation types, torsional wave amplitude variation types, and drilling rate and drilling pressure linkage modes.

3. The digital twin monitoring system for drilling and workover equipment according to claim 2, characterized in that, The deposition path reconstruction module includes: The cuttings collection and identification submodule acquires the cuttings particles collected during the return process, extracts the return time sequence and drilling depth records, binds the particle number with the corresponding drilling depth, and organizes them into a data group consisting of particle number, return time and drilling depth to generate particle return depth data. The path location mapping submodule, based on the particle return depth data, calls the fluid channel path record, matches the depth position according to the return time, matches the depth coordinates of the particle in the drilling structure, organizes them into a mapping set of particle number and depth position, and generates depth path mapping data. The deposition trajectory construction submodule applies pressure to the particle surface and records the corresponding radial deformation value based on the depth path mapping data. It merges particles deformed in the same direction according to the drilling depth interval, summarizes the deformation trajectories of the interval to construct a spatial distribution map, and obtains the return deposition deformation path map.

4. The digital twin monitoring system for drilling and workover equipment according to claim 3, characterized in that, The trend segment identification module includes: The trajectory dense positioning submodule obtains the densely distributed areas of the trajectory in the return deposition deformation path map, identifies the corresponding drilling depth number, extracts the drilling speed time series at the number, and combines the drilling depth and drilling speed in time order to generate a dense segment drilling speed sequence. The amplitude direction determination submodule extracts the drilling speed change data of the dense segment and edge segment positions based on the dense segment drilling speed sequence, calculates the drilling speed amplitude rate, determines whether the amplitude direction is consistent, calculates the amplitude deviation between segments, and marks whether they are synchronized to obtain the amplitude direction consistency mark. The trend segmentation construction submodule, based on the amplitude direction consistency marker, clusters the drilling depth numbers with the same adjacent marker state into continuous segments, arranges the numbers within the segments in chronological order, establishes a combination list of numbers and trend types, and obtains a set of spatial trend evolution segments.

5. The digital twin monitoring system for drilling and workover equipment according to claim 4, characterized in that, The differential pressure offset positioning module includes: The differential pressure extraction submodule acquires the pressure acquisition records of the drilling depth section covered by the spatial trend evolution segment set on the time axis. Based on the stratification position from the wellhead to the bottom of the well, it calls the stratification structure division parameters, extracts the pressure data in the continuous time period synchronously according to the stratification interval, and classifies the pressure value of each layer into the time horizontal sequence according to the sampling interval to obtain the stratified pressure sequence dataset. The amplitude calculation submodule calculates the pressure difference between the current sampling point and the adjacent sampling point based on the layered pressure sequence dataset, establishes a difference sequence, extracts the amplitude change rate between consecutive points in the difference sequence by layer, calculates the pressure change ratio of the point in the corresponding layer segment, compares the relative differences in amplitude changes between layers, and obtains the interlayer pressure amplitude difference value. The drilling depth point identification submodule identifies the direction of amplitude change of adjacent points between layers based on the interlayer pressure amplitude difference value, determines whether there are drilling depth points with opposite directions or significant offsets in the trend of difference change, and obtains a group of multiple pressure difference offset points.

6. The digital twin monitoring system for drilling and workover equipment according to claim 5, characterized in that, The oscillation linkage analysis module includes: The oscillation data extraction submodule obtains the drill string oscillation records within the corresponding time period of the multi-segment differential pressure offset point group, synchronously retrieves the drilling speed sequence within the corresponding time window, extracts the drill string axial amplitude, torsional amplitude and drilling speed value at the time point, constructs the joint change sequence of amplitude and drilling speed in chronological order, and generates the oscillation drilling speed joint sequence. The consistency screening submodule extracts the difference sequence between the amplitude change direction and the drilling speed change direction based on the oscillation drilling speed joint sequence, determines whether the two change directions are the same within a time period, and marks them as synchronous expansion and synchronous decline states. It then classifies and screens all time windows to obtain a set of synchronous markers for the oscillation speed direction. The linkage merging generation submodule, based on the vibration velocity direction synchronization mark set, categorizes the amplitude change, drilling speed change, and drilling pressure change values ​​within the corresponding time period of the synchronization mark into the same type of mark group, summarizes and merges them according to the oscillation direction, constructs a linkage linked list of the three changes in drilling pressure, drilling speed, and amplitude, and obtains the oscillation linkage response chain group.

7. The digital twin monitoring system for drilling and workover equipment according to claim 1, characterized in that, The system also includes a joint control sequence generation module: The joint control sequence generation module extracts the drilling depth and oscillation direction from the oscillation linkage response chain group, combines the deposition trend, pressure difference trend and trigger point information, sorts and filters priority groups, matches action instructions, writes them into the execution queue, and obtains the joint control operation execution sequence. The joint control operation execution sequence includes the trigger node drilling depth number, the corresponding action instruction set, and the time series sorting result.

8. A digital twin monitoring system for drilling and workover equipment according to claim 7, characterized in that, The joint control sequence generation module includes: The trigger information combination submodule retrieves the drilling depth and oscillation direction information listed in the oscillation linkage response chain group, extracts the deposition trend type and pressure difference change trend corresponding to the continuous trigger points of drill bit action, and constructs a trigger structure sequence according to the time sequence and drilling depth sequence to generate a joint control trigger information set. The priority group filtering submodule extracts the concentration of trigger frequency and amplitude variation, drilling speed variation and drilling pressure variation in the combination based on the joint control trigger information set. Combinations with high frequency and concentrated amplitude are sorted and marked as high priority groups. Combinations with trigger frequency lower than the set number threshold are removed to obtain the joint control priority structure group. The instruction queue writing submodule matches the executable action type corresponding to the trigger structure according to the joint control priority structure group, extracts the corresponding action instruction group and arranges them in order of trigger time, summarizes all high priority group corresponding instructions and writes them into the control queue structure to obtain the joint control operation execution sequence.

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