An integrated control chip device for an electric workover rig

Abstract

The present invention relates to the field of automation control technology, and specifically to a chip device for integrated control of an electric workover rig. In the present invention, through the refined analysis of operation data, the dynamic adjustment of the task priorities in the operation stage is realized, making the allocation of computing resources more accurate and improving the execution efficiency of key tasks. During the optimization of the drill string stress, the real-time monitoring of the lateral offset trend is introduced, and the additional load calculation is carried out in combination with the influence of formation rebound, making the overall stress of the drill string more balanced and reducing the problem of abnormal stress concentration caused by lateral offset. The torque adjustment mechanism is dynamically optimized based on the force distribution of the drill bit, ensuring that the torque adjustment direction matches the force trend of the drill bit, reducing the abnormal wear caused by uneven drill bit force, and improving the drilling stability. The prediction of the drilling depth adopts trend analysis under various bit weights, combined with the formation permeability mapping relationship, making the bit weight adjustment more reasonable and reducing the risk of sudden change in the drill bit load.

Description

Technical Field

[0001] The present invention relates to the technical field of automatic control, and particularly to a chip device for integrated control of an electric workover rig. Background Art

[0002] The technical field of automatic control encompasses the design, development, and application of various automatic equipment and systems, aiming to improve production efficiency, reduce manual intervention, and optimize operation processes through intelligent control means. The core content of this technical field includes signal acquisition, data processing, control strategy execution, and feedback regulation, and typically involves aspects such as sensor technology, embedded systems, industrial communication protocols, and power electronics control.

[0003] Among them, the chip system for integrated control of an electric workover rig refers to a dedicated control system applied to workover operations. Its core lies in achieving real-time coordination and control of key components of the workover rig through chip integration, including the acquisition and analysis of workover rig operation status data, precise control of the power system, real-time adjustment of operation parameters, and implementation of safety protection mechanisms. The specific methods include using an embedded microcontroller to complete the motor drive control of workover equipment, obtaining the working status of downhole tools and surface equipment through analog and digital signal interfaces, and performing data processing and correction by combining customized logic operation circuits.

[0004] In workover operations, the existing technology has a problem of rigidity in job task priority scheduling, unable to dynamically adjust according to changes in the job stage, resulting in unbalanced allocation of computing resources, limited execution efficiency of some key tasks, and affecting the overall coordination of the operation. During the process of adjusting the drill string force, due to the lack of precise monitoring of the lateral offset trend, the force correction mainly relies on static calculations and is difficult to reflect the influence of formation rebound in real time, resulting in lagged force adjustment and increasing the risk of abnormal drill string bending stress. The torque adjustment relies on preset parameters for correction, failing to fully consider the real-time force state of the drill bit, resulting in lagged torque adjustment, affecting the drilling stability, and possibly causing bit eccentric wear or abnormal damage. The adjustment of drilling depth mainly relies on the empirical value calculation of fixed parameters, lacking a fine model of formation permeability, resulting in low precision of weight-on-bit adjustment and being difficult to dynamically adapt to changes in different formation conditions. During the data interaction process, the data format conversion of the existing technology lacks pertinence and the instruction stream optimization is insufficient, resulting in delayed execution of control instructions, affecting the real-time response ability of drilling control, and reducing the overall collaborative control efficiency of the system. Summary of the Invention

[0005] The purpose of the present invention is to solve the drawbacks existing in the prior art, and to propose a chip device for integrated control of an electric workover rig.

[0006] To achieve the above purpose, the present invention adopts the following technical solution: A chip device for integrated control of an electric workover rig includes:

[0007] The operation stage scheduling module obtains the operation data of downhole equipment, determines the current operation stage, adjusts the execution priority of the operation stage calculation tasks, and generates the calculation task priority allocation result;

[0008] The drill string force correction module analyzes the lateral offset increment of the current task drill string within a specified time according to the task execution priority in the calculation task priority allocation result, corrects the overall force balance state of the drill string, and generates the drill string lateral force correction result;

[0009] The motor torque adjustment module analyzes the current force distribution of the drill bit according to the drill string lateral force correction result, determines the factors affecting torque adjustment, adjusts the output direction of the motor torque, and generates the drill bit torque optimization result;

[0010] The drilling depth prediction module obtains the drilling speed after torque optimization in the drill bit torque optimization result, analyzes the influence of the weight on bit adjustment on the drilling depth, predicts the future drilling trend of the drill bit under various weight on bit conditions, and generates the drilling depth prediction result;

[0011] The data interaction module converts the drilling depth prediction result into a format recognizable by the chip, performs the linkage adjustment of the drilling depth and the drill bit advancement rate, and generates the integrated control instruction stream of the electric workover rig.

[0012] As a further solution of the present invention, the calculation task priority allocation result includes a calculation task list, a task importance weight, a task scheduling parameter, and a calculation resource allocation value; the drill string lateral force correction result is specifically a drill string lateral offset correction value, a formation rebound additional load correction value, and a drill string force balance adjustment parameter; the drill bit torque optimization result includes a drill bit force balance parameter, a torque adjustment direction, and a weight on bit optimization coefficient; the drilling depth prediction result is specifically a drilling depth interval, a weight on bit adjustment parameter, a predicted value of the drill bit advancement rate, and a formation permeability mapping relationship; the integrated control instruction stream of the electric workover rig includes chip instruction formatted data, a drilling depth control instruction, a drill bit advancement rate adjustment instruction, and data transmission verification information.

[0013] As a further solution of the present invention, the operation stage scheduling module includes:

[0014] The operation status identification sub-module obtains the downhole equipment status, wellhead load, motor torque, and fluid pressure data, determines that the current operation stage belongs to hoisting, running, circulating, stuck drill warning, or construction operation, analyzes the data processing requirements for each operation stage, determines the calculation tasks required for the current stage, and generates the operation stage calculation requirement analysis result;

[0015] The calculation task screening sub-module is based on the operation stage calculation requirement analysis result and uses the formula:

[0016] ;

[0017] Resource priority of the computing task to generate a screening and sorting value for the computing task;

[0018] Among them, represents the requirement weight of task , represents the resource requirement value of task , represents the total value of the weighted resources of all tasks, is the total number of tasks, is the index variable in the summation symbol, indicating the number of each task;

[0019] The task priority adjustment sub-module adjusts the execution priority of the computing task based on the screening and sorting value of the computing task, updates the task scheduling parameters, and generates a computing task priority allocation result.

[0020] As a further solution of the present invention, the drill string force correction module includes:

[0021] The lateral offset monitoring sub-module obtains the lateral offset angle, formation resilience moment, and borehole shape change information of the drill string of the current task according to the task execution priority in the computing task priority allocation result, compares the current lateral offset angle of the drill string with the offset data, calculates the offset increment per unit time, judges the offset trend according to the borehole shape change, analyzes the overall lateral force trend of the drill string within a specified time, and generates drill string lateral offset trend data;

[0022] The additional load calculation sub-module is based on the drill string lateral offset trend data and uses the formula:

[0023] ;

[0024] to calculate the additional load of the drill string ;

[0025] Among them, represents the th group of data of the formation resilience moment, represents the total resultant moment of all formation resilience moments, represents the number of data groups of the formation resilience moment, that is, the total number of formation resilience moments involved, represents the borehole curvature influence coefficient, represents the borehole shape change angle, represents the additional load component caused by the borehole shape change, is the total number of borehole shape change angles, ​is the index variable in the summation symbol, used to traverse all borehole shape change terms;

[0026] Based on the additional load of the drill string, the force balance adjustment sub-module determines whether the lateral offset exceeds a predetermined safety range, sets the threshold standard for the safe offset range. If it exceeds, it analyzes the force distribution of the drill string under various bending trends, adjusts the bending trend of the drill string, corrects the overall force balance state of the drill string, and generates the drill string lateral force correction result.

[0027] As a further solution of the present invention, the motor torque adjustment module includes:

[0028] The bit force monitoring sub-module obtains the lateral force and drill pipe deflection information of the current task bit, and uses the formula:

[0029] ;

[0030] Calculate the lateral force change rate ;

[0031] where, and are the lateral force values of the bit at times and respectively;

[0032] Based on the lateral force change rate, the torque adjustment and optimization sub-module compares the drill pipe deflection change trend, determines whether the lateral force exceeds the force threshold, analyzes the current force distribution of the bit according to the drill string lateral force correction result, determines the factors affecting torque adjustment, and when the force threshold is exceeded, adjusts the motor torque output direction to match the lateral force trend of the bit, and generates the bit torque optimization result.

[0033] As a further solution of the present invention, the drilling depth prediction module includes:

[0034] The drilling speed analysis sub-module obtains the drilling speed after torque optimization in the bit torque optimization result, analyzes the influence of the weight on bit adjustment on the drilling depth, screens the parameter variables affecting the drilling depth, and obtains the drilling depth influence parameter set;

[0035] The drilling depth calculation sub-module is based on the drilling depth influence parameter set, and according to the permeability data record of each formation, uses the formula:

[0036] , ;

[0037] Calculate the minimum value and the maximum value of the optimal drilling depth interval at the current bit position, and obtain the optimal drilling depth interval;

[0038] Wherein, is the bit penetration rate corresponding to the group of drilling parameters, is the duration of the measurement period, is the number of drilling times during the measurement period, is the correction term for the force between the bit and the wellbore wall, is the change range of the bit penetration rate;

[0039] The drilling trend prediction sub-module analyzes the drilling trends under various WOB conditions based on the mapping relationship curve of pressure and permeability in the optimal drilling depth interval, predicts the drilling depth distribution of the bit during future drilling, and generates a drilling depth prediction result.

[0040] As a further solution of the present invention, the data interaction module includes:

[0041] The data format conversion sub-module converts the drilling depth prediction result into a format recognizable by the chip, parses the data fields and matches the chip input standard, extracts key data items, including the drilling depth interval, the bit propulsion load, and the WOB adjustment range, re-packages the data stream according to the chip instruction encoding specification to verify the integrity and consistency of the data, and generates the packaged chip instruction data;

[0042] The instruction transmission and linkage sub-module calls the data transmission interface to write the packaged chip instruction data into the chip, performs the linkage adjustment of the drilling depth and the bit propulsion rate, and generates an integrated control instruction stream for the electric workover rig.

[0043] Compared with the prior art, the advantages and positive effects of the present invention are as follows:

[0044] In the present invention, through the refined analysis of operation data, the dynamic adjustment of the task priorities in the operation stage is realized, so that the allocation of computing resources is more accurate, and the execution efficiency of key tasks is improved. During the optimization of the drill string force, the real-time monitoring of the lateral offset trend is introduced, and the additional load calculation is combined with the influence of formation rebound, so that the overall force of the drill string is more balanced, and the abnormal stress concentration problem caused by lateral offset is reduced. The torque adjustment mechanism is dynamically optimized based on the bit force distribution, ensuring that the torque adjustment direction matches the bit force trend, reducing the abnormal wear caused by uneven bit force, and improving the drilling stability. The drilling depth prediction uses trend analysis under various WOB conditions and combines the formation permeability mapping relationship to improve the drilling depth prediction accuracy, make the WOB adjustment more reasonable, and reduce the risk of sudden change in the bit load. During the data interaction process, the instruction stream is optimized through data format conversion, so that the drilling depth and the bit propulsion rate form a linkage adjustment, improving the real-time performance and response speed of the control system, and ensuring the control accuracy during the operation process. Description of the Drawings

[0045] Figure 1 is the device flow chart of the present invention;

[0046] Figure 2 is the flow chart of the operation stage scheduling module of the present invention;

[0047] Figure 3 is the flow chart of the drill string force correction module of the present invention;

[0048] Figure 4 is the flow chart of the motor torque adjustment module of the present invention;

[0049] Figure 5 is the flow chart of the drilling depth prediction module of the present invention;

[0050] Figure 6 is the flow chart of the data interaction module of the present invention. Specific embodiments

[0051] In order to make the objectives, technical solutions and advantages of the present invention clearer and more understandable, the present invention will be further described in detail below in conjunction with the accompanying drawings and embodiments. It should be understood that the specific embodiments described herein are only used to explain the present invention and are not used to limit the present invention.

[0052] In the description of the present invention, it should be understood that the orientation or positional relationship indicated by terms such as "length", "width", "upper", "lower", "front", "rear", "left", "right", "vertical", "horizontal", "top", "bottom", "inner", "outer", etc. is based on the orientation or positional relationship shown in the accompanying drawings. It is only for the convenience of describing the present invention and simplifying the description, rather than indicating or implying that the device or element referred to must have a specific orientation, be constructed and operated in a specific orientation, and therefore should not be construed as a limitation of the present invention. In addition, in the description of the present invention, "a plurality of" means two or more, unless otherwise specifically defined.

[0053] Please refer to Figure 1 , a chip device for integrated control of an electric workover rig includes:

[0054] The operation stage scheduling module obtains the operation data of downhole equipment, determines the current operation stage, adjusts the execution priority of the operation stage calculation tasks, and generates a calculation task priority allocation result;

[0055] The drill string force correction module analyzes the lateral offset increment of the current task drill string within a specified time according to the task execution priority in the calculation task priority allocation result, corrects the overall force balance state of the drill string, and generates a drill string lateral force correction result;

[0056] The motor torque adjustment module analyzes the current force distribution of the drill bit based on the correction result of the lateral force on the drill string, determines the factors affecting torque adjustment, adjusts the output direction of the motor torque, and generates the optimized drill bit torque result;

[0057] The drilling depth prediction module obtains the drilling speed after torque optimization in the optimized drill bit torque result, analyzes the influence of weight on bit adjustment on the drilling depth, predicts the future drilling trend of the drill bit under various weight on bit conditions, and generates the drilling depth prediction result;

[0058] The data interaction module converts the drilling depth prediction result into a format recognizable by the chip, performs the linkage adjustment of the drilling depth and the drill bit advancement rate, and generates the integrated control instruction stream for the electric workover rig;

[0059] The calculation task priority allocation result includes the calculation task list, task importance weight, task scheduling parameter, and calculation resource allocation value; the correction result of the lateral force on the drill string is specifically the correction value of the lateral offset of the drill string, the correction value of the additional load due to formation rebound, and the drill string force balance adjustment parameter; the optimized drill bit torque result includes the drill bit force balance parameter, torque adjustment direction, and weight on bit optimization coefficient; the drilling depth prediction result is specifically the drilling depth interval, weight on bit adjustment parameter, predicted drill bit advancement rate, and formation permeability mapping relationship; the integrated control instruction stream for the electric workover rig includes chip instruction formatted data, drilling depth control instruction, drill bit advancement rate adjustment instruction, and data transmission verification information.

[0060] Please refer to Figure 2 , the operation stage scheduling module includes:

[0061] The operation status identification sub-module obtains the downhole equipment status, wellhead load, motor torque, and fluid pressure data, determines whether the current operation stage belongs to tripping out, tripping in, circulation, stuck drill warning, or construction operation, analyzes the data processing requirements for each operation stage, determines the calculation tasks required for the current stage, and generates the analysis result of the calculation requirements for the operation stage;

[0062] Obtain the downhole equipment status, wellhead load, motor torque, and fluid pressure data, extract data from different monitoring points respectively, and perform time series matching to ensure the time synchronization of data acquisition. For example, during tripping out, the wellhead load will have periodic fluctuations due to the lifting of the drill string, and the motor torque will change with the movement of the drill string. On this basis, set the normal operation load fluctuation range in combination with historical operation data, compare the real-time data with the reference data to identify abnormal load changes. At the same time, judge the circulating fluid status according to the fluid pressure change rate. When the pressure fluctuation exceeds the set threshold (such as ±5%), it may indicate that a stuck drill or fluid channel blockage occurs downhole, thus triggering further operation stage identification. See Table 1 for details.

[0063] Table 1 Wellhead Load and Motor Torque Threshold Setting Table:

[0064]

[0065] According to the real-time monitored equipment status data, substitute the data into Table 1 for comparison. For example, if the currently measured wellhead load is 520 kN, the motor torque is 2600 N·m, and the fluid pressure is 1.2 MPa, it matches the "stuck drill warning" stage. The system can further calculate the changing trend of the drill string force and trigger countermeasures, and then analyze the data processing requirements at this stage. For example, in the stuck drill warning stage, the lateral force of the drill string changes frequently, and it is necessary to increase the data processing tasks for torque and the bending trend of the drill string. While in the drill-out stage, it is necessary to focus on analyzing the influence of the inertial load of the drill string. Then, the system compares the computing resource requirements of each task, calculates the execution priority of the task list, and adjusts the arrangement order of the tasks according to the resource utilization rate, and finally generates the computing requirement parameters for the operation stage.

[0066] The computing task screening sub-module is based on the analysis results of the computing requirements for the operation stage and uses the formula:

[0067] ;

[0068] Computing task Resource priority to generate the computing task screening and sorting value;

[0069] Among them, represents the requirement weight of task , represents the resource requirement value of task , represents the total value of the weighted resources of all tasks. For example, if the current total computing resource value is 1000, the resource requirement for the drill string force analysis task is 600, the resource requirement for the torque adjustment calculation task is 300, and the resource requirement for the drilling depth prediction task is 100. The task requirement weights can be set according to the computing volume, execution frequency, and real-time requirements of the tasks. For example, tasks with a larger computing volume can be given a higher weight to obtain computing resources preferentially, and tasks with higher real-time requirements also need to increase their priorities. During the screening process, the system first sets the initial weight values of the tasks according to the different requirements of the operation stage. For example, the weight of the drill string force analysis is set to 0.6, the weight of the torque adjustment calculation is set to 0.3, and the weight of the drilling depth prediction is set to 0.1. is the total number of tasks, is the index variable in the summation symbol, representing the number of each task. The specific data is shown in Table 2.

[0070] Table 2 Task Weight Setting Table:

[0071]

[0072] The resource priorities of each task are calculated as follows:

[0073] ;

[0074] ;

[0075] ;

[0076] According to the calculation results, the priority of the drill string force analysis task is the highest. Therefore, when calculating the task resource allocation, the computing resources of this task should be guaranteed first, and finally the calculation task screening and sorting value is generated.

[0077] The task priority adjustment sub-module adjusts the execution priority of the calculation task based on the calculation task screening and sorting value, updates the task scheduling parameters, and generates the calculation task priority allocation result;

[0078] Based on the calculation task screening and sorting value, the task execution parameters are called to adjust the execution priority of the calculation task to ensure the reasonable allocation of computing resources. During the process of computing resource allocation, the system allocates the computing resources that each task can obtain according to the demand weight of the task and the total amount of computing resources. The resource proportion of a calculation task is obtained by multiplying the demand weight of the task by its required computing resources and then dividing by the total resource demand of all tasks. For example, if the current total amount of computing resources is 1000 units, and the computing resource requirements of tasks A, B, and C are 600, 300, and 100 units respectively, then the total resource demand is 1000 units. The resource proportion of each task is equal to the product of its resource demand and task weight divided by the total resource demand. On this calculation basis, if the weight of task A is 0.6, the weight of task B is 0.3, and the weight of task C is 0.1, then the resource proportions of tasks A, B, and C can be obtained by multiplying their resource demands by the task weights and then dividing by the total demand. Among them, the calculation method of task A is 600×0.6 / (600×0.6 + 300×0.3 + 100×0.1). Similarly, calculate the resource proportions of tasks B and C. The final result is that task A accounts for 67%, task B accounts for 25%, and task C accounts for 8%. Based on this calculation result, the system determines whether it is necessary to adjust the execution priority of the task. If the resource proportion of a certain task does not reach the minimum execution standard, the priority of this task is reduced, and the resources are tilted towards high-priority tasks. Finally, the task scheduling parameters are updated to generate the calculation task priority allocation result.

[0079] Please refer to Figure 3 , the drill string force correction module includes:

[0080] The lateral offset monitoring sub-module obtains the lateral offset angle, formation resilience moment, and borehole shape change information of the drill string for the current task according to the task execution priority in the calculation task priority allocation result, compares the current lateral offset angle of the drill string with the offset data, calculates the offset increment per unit time, judges the offset trend according to the borehole shape change, analyzes the overall lateral force trend of the drill string within a specified time, and generates drill string lateral offset trend data;

[0081] Obtain the lateral offset angle, formation resilience moment, and borehole shape change information of the drill string for the current task. The acquisition of each data item needs to be monitored in real time through the downhole sensor array. For example, the lateral offset angle can be measured by the drill string inertial sensor, and compared with the historical operation data to judge the displacement trend of the drill string within a specific time. The measurement of the formation resilience moment depends on the drill string force monitoring system. The strain data under different drilling depths are mainly recorded by the downhole strain gauge and analyzed through the resilience moment calculation model. The borehole shape change needs to obtain the wellbore wall profile data through the downhole imaging tool and calculate the borehole eccentricity in combination with the drill string offset trend. After the data is obtained, the system needs to compare the current lateral offset angle with the historical offset data to calculate the offset increment per unit time. This process can be achieved by calculating the displacement difference between the head and tail of the drill string in a continuous time period. For example, if the offset angle change of the drill string increases from 5° to 7° within 1 minute, the increment per unit time is 2° / min. Subsequently, the system needs to combine the borehole shape data to judge the offset trend. If the borehole curvature is greater than the drill string bending radius, the deformation amount of the drill string structure under this borehole shape needs to be calculated. This calculation needs to consider the material properties of the drill string, borehole curvature, and external load. For example, in a well section with a borehole curvature of 12° / m and a drill string bending radius of 10° / m, the drill string will undergo additional deformation. This deformation can be calculated using the stress-strain formula, and thus the additional deformation amount of the drill string structure can be obtained, and then the overall lateral force trend of the drill string within a specified time can be analyzed to generate drill string lateral offset trend data.

[0082] The additional load calculation sub-module is based on the drill string lateral offset trend data and uses the formula:

[0083] ;

[0084] Calculate the additional load of the drill string ;

[0085] where, represents the group data of the formation resilience moment. The acquisition method is to measure the drill string resilience moment at different well depths and calculate the mean value of the resilience moment in each area in combination with the drill string force distribution; represents the total resultant moment of all formation resilience moments, which is obtained by accumulating the resilience moment data of each measuring point of the drill string, represents the number of data groups of the formation resilience moment; represents the wellbore curvature influence coefficient, which is calculated by combining the wellbore deviation measurement values with the formation type. The experimental method includes measuring the inclination angle between the drill bit and the wellbore wall and evaluating it in combination with the wellbore smoothness; represents the angle of change in wellbore shape. In the downhole measurement system, the inclination angle of the drill string is measured by a gyroscope and its rate of change is calculated; represents the additional load component caused by the change in wellbore shape, is the total number of angles of change in wellbore shape, is the index variable in the summation symbol, used to traverse all terms of the change in wellbore shape.

[0086] If the values at the measurement points of the three groups of data are 450 N·m, 490 N·m, and 530 N·m respectively, and the values at the two groups of measurement points are 0.8 and 1.1 respectively, are 3.5° and 4.2° respectively, then the additional load is calculated as follows:

[0087] ;

[0088] This result indicates that under the current downhole conditions, the additional load on the drill string is 1212.44 N, and this value can be used for subsequent force adjustment analysis.

[0089] Based on the additional load of the drill string, the force balance adjustment sub-module determines whether the lateral offset exceeds the predetermined safety range, sets the threshold standard for the safe offset range. If it exceeds, it analyzes the force distribution of the drill string under different bending trends, adjusts the bending trend of the drill string, corrects the overall force balance state of the drill string, and generates the corrected result of the lateral force of the drill string;

[0090] Determine whether the lateral offset exceeds the predetermined safety range, set the threshold standard for the safe offset range. This threshold is usually measured through wellbore stability experiments. For example, in a certain drilling project, the safe offset range is determined to be 5° through wellbore wall strength tests. If the calculated lateral offset is greater than this value, adjustment operations need to be performed. During adjustment, the force distribution of the drill string under different bending trends needs to be analyzed, and the force state of the drill string needs to be measured. For example, the force on the drill string measured at an offset angle of 6° is 4000 N, and the force measured at an offset angle of 4° is 3500 N. Then the calculated force change trend can be used to formulate the drill string adjustment plan. During the adjustment process, the bending trend of the drill string needs to be optimized, the overall force balance state of the drill string needs to be corrected, and finally the balance moment of the drill string in the wellbore after correction is calculated to generate the corrected result of the lateral force of the drill string.

[0091] Please refer to Figure 4 , the motor torque adjustment module includes:

[0092] The drill bit force monitoring sub-module obtains the lateral force and drill pipe deflection information of the current task drill bit. The lateral force can be measured by a triaxial force sensor installed on the drill bit, and the drill pipe deflection can be obtained by a laser rangefinder installed on the drill pipe to measure its deformation. The formula is used:

[0093] ;

[0094] Calculate the lateral force change rate ;

[0095] Among them, and are the lateral force values of the drill bit at time and respectively, with the unit of N. The time interval is calculated in seconds.

[0096] For example, in a drilling operation, the lateral force of a certain drill bit increased from 850 N to 1300 N within 5 seconds, then the calculation is: , after calculating the lateral force change rate, the system compares the historical force data and judges whether the force change has an abnormal trend. For example, within three consecutive time periods, if continues to be greater than 80 N / s, it can be judged that the force change is abnormal, and finally the lateral force change rate data is obtained.

[0097] The torque adjustment and optimization sub-module, based on the lateral force change rate, compares the change trend of the drill pipe deflection, judges whether the lateral force exceeds the force threshold, analyzes the current force distribution of the drill bit according to the correction result of the drill string lateral force, determines the factors affecting the torque adjustment, and adjusts the motor torque output direction to match the lateral force trend of the drill bit when the force threshold is exceeded, generating the drill bit torque optimization result;

[0098] Based on the lateral force change rate data, the calculated lateral force change rate is 90 N / s. It is necessary to further compare the changing trend of the drill pipe deflection. The drill pipe deflection is obtained through the drill pipe deformation monitoring system. This system installs deformation sensors at different positions of the drill pipe to measure the bending degree of the drill pipe under the stressed state. For example, in a certain measurement, the drill pipe deflection increases from 1.2° to 2.8°, so the deflection increases by 1.6°. The system calculates the correlation between the lateral force change rate and the changing trend of the deflection to judge whether the force trend is normal. If the lateral force change rate is greater than 80 N / s within a short time (such as 5 seconds) and the deflection increase exceeds 1.5°, it indicates that the drill pipe is in a large bending stress state, and it is necessary to further judge whether it exceeds the force threshold. The force threshold is set according to the material characteristics of the drill pipe and the drilling working conditions. For example, the limit deflection of a certain type of drill pipe is set to 3.5°. If the measured deflection exceeds 3.5°, or the current deflection change trend combined with the force change rate is estimated to exceed 3.5° within 10 seconds, it can be judged that the force is over the limit. The system analyzes the current force distribution of the drill bit according to the correction result of the lateral force of the drill string, and calculates its force direction in combination with the bit pose data to determine the key factors affecting the torque adjustment, including the drill pipe rigidity, the wellbore friction coefficient, the bit offset angle, etc. If the calculated lateral force change rate is 90 N / s and the current deflection of the drill pipe has reached 2.8°, it is predicted that the deflection may increase to 4.0° after 5 seconds, exceeding the force threshold. At this time, it is necessary to adjust the output direction of the motor torque. The system adjusts the motor torque to match the lateral force trend of the drill bit, optimizes the torque transmission method, and avoids additional deformation of the drill pipe caused by uneven force. For example, if the currently measured torque value is 4600 N·m, and the normal torque range of this drill bit in the hard formation is 4000 - 4500 N·m, the part exceeding 4500 N·m will cause additional lateral force. At this time, the motor torque is adjusted to 4400 N·m, and the torque output direction is optimized to stably output in the direction with the least influence of the wellbore friction, so as to reduce the changing trend of the lateral force of the drill pipe and ensure the stability of the torque during the drilling process, and finally generate the optimized result of the drill bit torque.

[0099] Please refer to Figure 5 , the drilling depth prediction module includes:

[0100] The drilling speed analysis sub-module obtains the drilling speed after torque optimization in the optimized result of the drill bit torque, analyzes the influence of the weight on bit adjustment on the drilling depth, screens the parameter variables affecting the drilling depth, and obtains the set of parameters affecting the drilling depth;

[0101] Obtain the drilling speed after torque optimization in the drill bit torque optimization result, measure the drill bit rotation rate, the change in weight on bit, and the downhole drill cuttings removal rate. When measuring the drill bit rotation rate, the rig control system records the angular velocity of the drill bit per unit time. For example, within a certain period of time, the measured angular velocity of the drill bit is 120 rpm, that is, it rotates 120 times per minute. From this value, the linear velocity and torque change of the drill bit can be deduced. The weight-on-bit data is measured by the bottomhole sensor, recording the actual force on the drill bit at the bottom of the well. For example, in a certain drilling operation, the measured weight on bit is 80 kN. The downhole drill cuttings removal rate is fed back by the mud circulation system, and the efficiency of drill cuttings removal is measured by calculating the volume change rate of the mud carrying drill cuttings. For example, within 10 minutes, the measured volume change of the mud carrying drill cuttings is 15 L, then the drill cuttings removal rate is 1.5 L / min. After the system records the above parameters, compare the change in drilling speed under different weight-on-bit conditions. For example, when the weight on bit is 80 kN, the measured drilling speed is 3.2 m / h, while when the weight on bit is 100 kN, the drilling speed increases to 4.1 m / h. The system screens the key parameters affecting the drilling depth, including weight on bit, rotation rate, formation hardness, mud density, etc., and calculates the influence weights of these parameters. For example, under a certain formation condition, the measured influence weight of the weight on bit is 0.4, the weight of the rotation rate is 0.3, the weight of the formation hardness is 0.2, and the weight of the mud density is 0.1. Finally, extract the dominant variables and obtain the parameter set affecting the drilling depth.

[0102] The drilling depth calculation sub-module, based on the parameter set affecting the drilling depth, according to the permeability data record of each formation, uses the formula:

[0103] , ;

[0104] Calculate the minimum value and the maximum value of the optimal drilling depth interval at the current drill bit position to obtain the optimal drilling depth interval;

[0105] where, is the bit penetration rate corresponding to the th set of drilling parameters, with the unit of m / h (meters per hour); is the duration of the measurement period, with the unit of h (hours); is the number of drilling times during the measurement period (for normalization calculation), dimensionless; is the correction term for the force between the drill bit and the wellbore, with the unit of m, used to correct the drilling depth; is the change range of the bit penetration rate, with the unit of m / h, used to calculate the maximum drilling depth.

[0106] If at a certain well section, the bit penetration rates of three measurement points are measured They are 2.5 m / h, 3.0 m / h, and 3.2 m / h respectively, and the measurement period is set to 2 hours, and the number of drilling times during the measurement period is 3, and the correction term for the force between the drill bit and the wellbore is set to 0.3 m, and the change range of the drill bit penetration rate is set to 0.5 m / h.

[0107] Calculate the minimum drilling depth:

[0108] ;

[0109] Calculate the maximum drilling depth:

[0110] ;

[0111] The final result shows that the optimal drilling depth range is [5.5 m, 7.1 m], that is, the drilling depth of the current drill bit in this well section should be controlled between 5.5 m and 7.1 m to ensure stable drilling and reduce wellbore damage.

[0112] The drilling trend prediction sub-module maps the relationship curve between pressure and permeability based on the optimal drilling depth range, analyzes the drilling trend under various bit weights, predicts the drilling depth distribution of the drill bit during future drilling, and generates the drilling depth prediction result;

[0113] Call the data of the optimal drilling depth range [5.5 m, 7.1 m], further establish the relationship curve between bit weight and permeability, and measure the permeability parameters corresponding to different bit weight values. For example, when the bit weight is 80 kN, the measured permeability is 0.25 D, and when the bit weight is 100 kN, the measured permeability is 0.18 D. The system predicts the drilling trend based on these data. Combining with the drilling depth calculation result, the system needs to analyze the future drilling trend under different bit weight conditions, calculate the drilling rate variation within the optimal drilling depth range [5.5 m, 7.1 m], and predict the depth development range of the drill bit during subsequent drilling. The drilling rate is greatly affected by the bit weight. For example, at a bit weight of 90 kN, the actual measurement is 3.8 m / h, and when the bit weight is increased to 95 kN, it increases to 4.1 m / h. Based on this change trend, the system simulates the future bit weight change, calculates the future drilling depth range under different bit weights. Assume that the current drill bit has drilled to 5.5 m and plans to continue drilling in the next 2 hours, then calculate the future drilling depth according to the measured data: , . Among them, and respectively represent the minimum and maximum values of the future drilling depth interval, with the unit of m; and are the minimum and maximum bit penetration rates corresponding to the current drilling depth interval, with the unit of m / h; is the prediction period, with the unit of h. Assume the WOB range is from 85 kN to 100 kN, and the measured bit penetration rates at different WOB values are as follows: at 85 kN, m / h; at 100 kN, m / h. Then substitute into the calculation: , . Finally, the predicted drilling depth interval within the next 2 hours is [12.5 m, 16.1 m], and this value can be used for formulating the WOB adjustment plan. The system will further analyze the impact of different WOB adjustment strategies on the future drilling depth and generate the drilling depth prediction result.

[0114] Please refer to Figure 6 , the data interaction module includes:

[0115] The data format conversion sub-module converts the drilling depth prediction result into a format recognizable by the chip, parses the data fields and matches the chip input standard, extracts key data items, including the drilling depth interval, bit advancement load, and WOB adjustment amplitude, and repackages the data stream according to the chip instruction encoding specification to verify the data integrity and consistency, and generates the encapsulated chip instruction data;

[0116] First, format the original drilling data. For example, convert the drilling depth interval data from floating-point format to 16-bit integer format to reduce storage occupancy. Store the bit advancement load in kN and quantify the load change rate. Normalize the WOB adjustment amplitude based on the WOB reference value and then store it. Subsequently, repackage the data stream according to the chip instruction encoding specification. For example, the instruction header contains an 8-bit data identifier, and then the data fields are arranged in sequence, including the 16-bit drilling depth interval, 32-bit advancement load, and 16-bit WOB adjustment amplitude. Verify the data integrity and consistency, calculate the data check value using CRC (Cyclic Redundancy Check). If the calculated check value is consistent with the stored check value, the data conversion is successful; otherwise, trigger the re-conversion process. Finally, obtain the encapsulated chip instruction data.

[0117] The instruction transmission and linkage sub-module calls the data transmission interface to write the encapsulated chip instruction data into the chip, performs the linkage adjustment of the drilling depth and bit advancement rate, and generates the integrated control instruction stream for the electric workover rig;

[0118] Call the encapsulated chip instruction data, load the data transmission interface, write the converted instructions into the chip, parse the instruction structure, and match the chip storage address. For example, store the drilling depth interval data in the 0x1000 address of the chip control register, the bit propulsion load in the 0x1002 address, and the drilling pressure adjustment range in the 0x1004 address. After the data is written, trigger the self-check function of the chip to confirm the data integrity. The system calls the control interface to perform the linkage adjustment of the drilling depth and the bit propulsion rate, and calculate the adjustment ratio of the propulsion rate. For example, if the drilling pressure adjustment range exceeds the preset threshold, reduce the propulsion rate by 5%. If the drilling depth interval exceeds the set range, pause the propulsion and adjust the drilling pressure. After the linkage adjustment is completed, generate the integrated control instruction stream for the electric workover rig.

[0119] The above is only the preferred embodiment of the present invention, and does not limit the present invention in other forms. Any person skilled in the art may use the disclosed technical content to make changes or modifications into equivalent embodiments with equivalent changes and apply them to other fields. However, as long as it does not depart from the technical solution content of the present invention, any simple modification, equivalent change and modification made to the above embodiments based on the technical essence of the present invention still belong to the protection scope of the technical solution of the present invention.

Claims

1. A chip device for integrated control of an electric workover rig, characterized in that: The device comprises: The operation phase scheduling module obtains the downhole equipment operation data, determines the current operation phase, adjusts the execution priority of the operation phase computing tasks, and generates the computing task priority allocation result; The drill string force correction module analyzes the lateral offset increment of the current task drill string within a specified time according to the task execution priority in the calculation task priority allocation result, corrects the overall force equilibrium state of the drill string, and generates a drill string lateral force correction result; The motor torque adjustment module analyzes the current force distribution of the drill bit according to the drill string lateral force correction result, determines the factors affecting the torque adjustment, adjusts the motor torque output direction, and generates the drill bit torque optimization result; The drilling depth prediction module obtains the drilling speed after torque optimization in the drill bit torque optimization result, analyzes the influence of drilling pressure adjustment on the drilling depth, predicts the drilling trend of the drill bit under various drilling pressure conditions in the future, and generates a drilling depth prediction result; The data interaction module converts the drilling depth prediction result into a chip-recognizable format, performs linkage adjustment of the drilling depth and the drill bit propulsion rate, and generates an integrated control instruction flow for the electric workover machine; The calculation task priority allocation result includes a calculation task list, task importance weight, task scheduling parameters, and calculation resource allocation value; the drill string lateral force correction result specifically includes a drill string lateral offset correction value, a formation rebound additional load correction value, and a drill string force balance adjustment parameter; the drill bit torque optimization result includes a drill bit force balance parameter, a torque adjustment direction, and a drilling pressure optimization coefficient; the drilling depth prediction result specifically includes a drilling depth range, a drilling pressure adjustment parameter, a drill bit propulsion rate prediction value, and a formation permeability mapping relationship; the electric well repair machine integrated control instruction stream includes chip instruction formatting data, drilling depth control instructions, drill bit propulsion rate adjustment instructions, and data transmission verification information.

2. The chip device for integrated control of an electric workover rig according to claim 1, characterized in that: The job phase scheduling module includes: The operation status identification submodule obtains the downhole equipment status, wellhead load, motor torque, and fluid pressure data, determines whether the current operation stage is a pull-out, drill-in, circulation, stuck drill warning, or construction operation, analyzes the data processing requirements of each operation stage, determines the computing tasks required for the current stage, and generates the calculation requirements analysis results for the operation stage; The calculation task screening submodule is based on the calculation demand analysis results of the operation stage, using the formula: ； Computational tasks Resource priority , generate the calculation task screening and sorting values; in, Representative tasks The demand weight, Representative tasks The resource demand value, Represents the total value of weighted resources of all tasks, is the total number of tasks, is the index variable in the summation symbol, indicating the number of each task; The task priority adjustment submodule adjusts the computing task execution priority based on the computing task screening ranking value, updates the task scheduling parameters, and generates a computing task priority allocation result.

3. The chip device for integrated control of an electric workover rig according to claim 2, characterized in that: The drill string force correction module comprises: The lateral deviation monitoring submodule obtains the lateral deviation angle, formation rebound torque, and wellbore morphology change information of the current task drill string according to the task execution priority in the calculation task priority allocation result, compares the current lateral deviation angle of the drill string with the deviation data, calculates the deviation increment per unit time, determines the deviation trend according to the wellbore morphology change, analyzes the overall lateral force trend of the drill string within the specified time, and generates the drill string lateral deviation trend data; The additional load calculation submodule is based on the drill string lateral deviation trend data and adopts the formula: ； Calculate additional loads on the drill string ; in, The first Group data, Represents the total moment of all formation rebound moments, The number of data sets representing the formation rebound moment, that is, the total number of formation rebound moments involved, represents the influence coefficient of wellbore curvature, Represents the change angle of wellbore shape, represents the additional load component caused by the change of wellbore morphology, is the total number of angles of wellbore morphology change, is the index variable in the summation symbol, used to traverse all wellbore morphology change items; The force balance adjustment submodule determines whether the lateral deviation exceeds a predetermined safety range based on the additional load of the drill string, and sets a threshold standard for the safety deviation range. If exceeded, the force distribution of the drill string under various bending trends is analyzed, the bending trend of the drill string is adjusted, the overall force balance state of the drill string is corrected, and a lateral force correction result of the drill string is generated.

4. The chip device for integrated control of an electric workover rig according to claim 3, characterized in that: The motor torque adjustment module comprises: The drill bit force monitoring submodule obtains the lateral force and drill rod deflection information of the current task drill bit using the formula: ； Calculate the rate of change of lateral force ; in, and The time and The lateral force value of the drill bit at ; The torque adjustment optimization submodule compares the lateral force change rate with the drill pipe deflection change trend to determine whether the lateral force exceeds the force threshold, analyzes the current force distribution of the drill bit according to the drill string lateral force correction result, determines the factors affecting the torque adjustment, and adjusts the motor torque output direction to match the drill bit lateral force trend when the force threshold is exceeded to generate a drill bit torque optimization result.

5. The chip device for integrated control of an electric workover rig according to claim 4, characterized in that: The drilling depth prediction module comprises: The drilling speed analysis submodule obtains the drilling speed after torque optimization in the drill bit torque optimization result, analyzes the influence of drilling pressure adjustment on drilling depth, screens parameter variables affecting drilling depth, and obtains a set of parameters affecting drilling depth; The drilling depth calculation submodule is based on the drilling depth influencing parameter set and the permeability data record of each formation, using the formula: ， ； Calculate the minimum value of the optimal drilling depth range for the current drill position and maximum value , get the optimal drilling depth range; in, It is The drill penetration rate corresponding to the set of drilling parameters, is the duration of the measurement period, is the number of drillings during the measurement period, is the correction term for the forces acting on the drill bit and the wellbore wall, is the range of variation of drill penetration rate; The drilling trend prediction submodule maps the pressure and permeability relationship curve based on the optimal drilling depth interval, analyzes the drilling trends under various drilling pressure conditions, and predicts the drilling depth distribution of the drill bit in the future drilling process to generate a drilling depth prediction result.

6. The chip device for integrated control of an electric workover rig according to claim 5, characterized in that: The data interaction module includes: The data format conversion submodule converts the drilling depth prediction result into a chip recognizable format, parses the data field and matches the chip input standard, extracts key data items, including the drilling depth range, the drill bit propulsion load, and the drilling pressure adjustment range, repackages the data stream according to the chip instruction encoding specification to verify the data integrity and consistency, and generates packaged chip instruction data; The instruction transmission and linkage submodule calls the data transmission interface to write the packaged chip instruction data into the chip, performs linkage adjustment of the drilling depth and the drill bit propulsion rate, and generates an integrated control instruction stream for the electric workover machine.

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