Methods, devices, equipment, and storage media for detecting the mechanical state parameters of drill strings.

Abstract

This application discloses a method, apparatus, device, and storage medium for detecting the mechanical state parameters of a drill string, relating to the field of downhole monitoring technology. The method includes: dividing the drill string into multiple drill string segments based on wellbore curvature; calculating the initial mechanical state parameters of all drill string segments based on a mechanical state parameter model in multiple threads of a parallel architecture; when a sudden change in downhole measurement data is detected, determining the locally abruptly changed well section in the drill string based on the downhole measurement data, and determining the multiple drill string segments to be inverted contained in the locally abruptly changed well section; and inputting the initial mechanical state parameters of the drill string segments to be inverted into the inversion mechanical state parameter model in multiple threads of a parallel architecture to obtain the inversion mechanical state parameters output by the inversion mechanical state parameter model.

Description

Technical Field

[0001] This application relates to the field of drilling downhole monitoring technology, specifically to a method, apparatus, equipment, and storage medium for detecting the mechanical state parameters of a drill string. Background Technology

[0002] In drilling operations, the friction between the drill string and the wellbore directly affects drilling efficiency and wellbore safety. Especially in complex well configurations, the drill string is subjected to the coupled effects of multiple pressures, which can easily lead to accidents such as buckling and stuck pipe. Therefore, it is necessary to obtain the mechanical state parameters of the drill string in real time and accurately.

[0003] Traditional methods for detecting mechanical state parameters typically employ a sequential calculation approach, performing a holistic analysis of the entire well section. However, during actual drilling, the drill string condition may change abruptly, requiring the rapid acquisition of the latest mechanical state parameters. Traditional methods, needing to complete calculations for the entire well section, often take minutes, making it difficult to meet the requirements of real-time monitoring while drilling. Furthermore, when local state changes occur, traditional methods still require repeated calculations for the entire well section, resulting in a significant waste of computational resources. Summary of the Invention

[0004] The purpose of this application is to provide a method, apparatus, device, and storage medium for detecting the mechanical state parameters of a drill string.

[0005] To achieve the above objectives, the first aspect of this application provides a method for detecting the mechanical state parameters of a drill string, the method comprising:

[0006] The drill string is divided into multiple drill string segments based on the wellbore curvature;

[0007] In multiple threads of a parallel architecture, the initial mechanical state parameters of all drill string segments are calculated based on a mechanical state parameter model.

[0008] In the event of a sudden change in downhole measurement data, the local abrupt change section in the drill string is determined based on the downhole measurement data, and multiple drill string segments to be inverted are identified within the local abrupt change section.

[0009] In multiple threads of the parallel architecture, the initial mechanical state parameters of the drill column segment to be inverted are input into the inversion mechanical state parameter model to obtain the inversion mechanical state parameters output by the inversion mechanical state parameter model.

[0010] In this embodiment of the application, the drill string is divided into multiple drill string segments according to the wellbore curvature, including: when the wellbore curvature is less than a first preset curvature, the drill string is segmented according to a first preset segment length; when the wellbore curvature is greater than or equal to the first preset curvature, the drill string is segmented according to a second preset segment length, wherein the first preset segment is greater than the second preset segment length.

[0011] In this embodiment of the application, the method further includes: selecting a corresponding fixed thread when the wellbore curvature of the drill string segment is less than a second preset curvature; and dynamically selecting a corresponding thread based on the number of tasks in the task queue of all threads when the wellbore curvature of the drill string segment is greater than or equal to the second preset curvature.

[0012] In this embodiment, the initial mechanical state parameters include initial friction, initial torque, initial hook load, and initial buckling critical load. The initial mechanical state parameters of all drill string segments are calculated based on the mechanical state parameter model, including: calculating the initial friction of the drill string segment based on the basic friction coefficient, friction transient coefficient, drill string rotational angular velocity, and the normal pressure exerted by the drill string segment on the wellbore; calculating the initial torque of the drill string segment based on the equivalent radius, tangential force, torque-curvature coupling factor, drill string bending stiffness, section rotation angle, and arc length along the drill string axis; calculating the initial hook load of the drill string segment based on the initial hook load, friction of the drill string segment, drill string rotational angular velocity, and axial displacement; and calculating the initial buckling critical load of the drill string segment based on the drill string bending stiffness, length coefficient, length of the drill string segment, and initial torque of the drill string segment.

[0013] In this embodiment of the application, the method further includes: determining the well inclination rate of the drill string segment; when the well inclination rate is less than or equal to a first preset rate, calculating the torque change of the drill string segment based on the wellbore curvature, the initial friction of the drill string segment, the normal constraint force, the mass per unit length of the drill string, the fluid resistance coefficient, and the well inclination rate; when the well inclination rate is greater than a second preset rate, calculating the bending moment of the drill string segment based on the initial hook load of the drill string segment, the well inclination angle of the drill string segment, the friction coefficient, the drill string rotation phase angle, the drill string bending stiffness, the section rotation angle, and the arc length along the drill string axis, wherein the first preset rate is less than the second preset rate; when the well inclination rate is greater than the first preset rate and less than or equal to the second preset rate, weighting the bending moment and the torque change based on preset weights to obtain the fused torque of the drill string segment.

[0014] In this embodiment, the initial mechanical state parameters include initial friction, initial torque, and initial hook load. The inversion mechanical state parameters include inversion friction, inversion torque, inversion hook load, and hook load at the wellhead. The initial mechanical state parameters of the drill string segment to be inverted are input into the inversion mechanical state parameter model to obtain the inversion mechanical state parameters output by the inversion mechanical state parameter model. This includes: calculating the friction increment of the drill string segment to be inverted based on static friction, torque axial gradient coefficient, initial torque of the drill string segment to be inverted, arc length along the drill string axis, and time-varying attenuation coefficient; updating the initial friction of the drill string segment to be inverted based on the friction increment and time step to obtain the inversion friction of the drill string segment to be inverted; and updating the initial friction of the drill string segment to be inverted based on the initial torque of the lower end face of the drill string segment to be inverted, the initial torque of the drill string segment to be inverted, the initial torque of the drill string segment to be inverted, the arc length along the drill string axis, and the time-varying attenuation coefficient. The equivalent radius of the drill string segment to be inverted, the inversion friction of the drill string segment to be inverted, the sign function of the rotation direction, the torque curvature coupling factor, the bending stiffness of the drill string, the section rotation angle, and the arc length along the drill string axis are used to obtain the inversion torque of the upper end face of the drill string segment to be inverted. The inversion hook load of the drill string segment to be inverted is obtained based on the initial hook load, the friction increment of the drill string segment to be inverted, and the sign function of the rotation direction. The hook load at the wellhead of the drill string segment to be inverted is obtained based on the axial force of the upper end face of the drill string segment to be inverted, the inversion friction of the drill string segment to be inverted, the sign function of the rotation direction, the buoyancy of the drill string per unit length in the drilling fluid, the gravitational acceleration, the length of the drill string segment to be inverted, the well inclination angle of the drill string segment to be inverted, the angular velocity of the drill string rotation, and the axial acceleration of the drill string segment to be inverted.

[0015] In this embodiment of the application, the method further includes: calculating the frictional change between the initial frictional resistance and the inverted frictional resistance, the torque change between the initial torque and the inverted torque, and the hook load change between the initial hook load and the inverted hook load; updating the time step based on the preset tolerance threshold and the frictional resistance increment when the maximum value among the frictional resistance change, torque change, and hook load change does not reach the preset tolerance threshold; and jumping to the step of calculating the frictional resistance increment of the drill string segment to be inverted based on the static frictional resistance, the torque axial gradient coefficient, the initial torque of the drill string segment to be inverted, the arc length along the drill string axis, and the time-varying attenuation coefficient.

[0016] A second aspect of this application provides a device for detecting the mechanical state parameters of a drill string, comprising: a memory configured to store instructions; a processor configured to retrieve instructions from the memory and, when executing the instructions, to implement a method for detecting the mechanical state parameters of the drill string.

[0017] The third aspect of this application provides a device for detecting the mechanical state parameters of a drill string, comprising: a device for detecting the mechanical state parameters of a drill string.

[0018] A fourth aspect of this application provides a machine-readable storage medium storing instructions for causing a machine to perform a method for detecting the mechanical state parameters of a drill string.

[0019] This solution introduces a parallel computing architecture, distributing the discretized drill string mechanical equations to a large number of threads for parallel solution, significantly shortening the calculation time of mechanical state parameters and realizing real-time high-precision simulation under drilling conditions. In addition, a dynamic triggering mechanism is adopted to start inversion calculation only in well sections where parameters change abruptly, avoiding repeated solutions for the entire well section. This ensures the analytical accuracy of key well sections and effectively improves the overall computational efficiency.

[0020] Other features and advantages of the embodiments of this application will be described in detail in the following detailed description section. Attached Figure Description

[0021] The accompanying drawings are provided to further illustrate the embodiments of this application and form part of the specification. They are used together with the following detailed description to explain the embodiments of this application, but do not constitute a limitation on the embodiments of this application. In the drawings:

[0022] Figure 1 The schematic diagram illustrates a flow chart of a method for detecting the mechanical state parameters of a drill string according to an embodiment of this application;

[0023] Figure 2 The schematic diagram illustrates a flow chart of a method for detecting the mechanical state parameters of a drill string according to an embodiment of this application;

[0024] Figure 3 This schematic diagram illustrates a mechanical model of a method for detecting the mechanical state parameters of a drill string according to an embodiment of this application.

[0025] Figure 4 The schematic diagram illustrates a flow chart of a method for detecting the mechanical state parameters of a drill string according to an embodiment of this application;

[0026] Figure 5 This schematic diagram illustrates a comparison of the calculated performance of different well sections using a drill string mechanical state parameter detection method according to an embodiment of this application.

[0027] Figure 6 This schematic diagram illustrates the structural block diagram of a drill string mechanical state parameter detection device according to an embodiment of this application;

[0028] Figure 7 The diagram illustrates the internal structure of a computer device according to an embodiment of this application. Detailed Implementation

[0029] To make the objectives, technical solutions, and advantages of the embodiments of this application clearer, the technical solutions of the embodiments of this application will be clearly and completely described below with reference to the accompanying drawings. It should be understood that the specific embodiments described herein are only for illustration and explanation of the embodiments of this application and are not intended to limit the embodiments of this application. All other embodiments obtained by those skilled in the art based on the embodiments of this application without creative effort are within the scope of protection of this application.

[0030] Figure 1 The illustration schematically shows a flowchart of a method for detecting the mechanical state parameters of a drill string according to an embodiment of this application. Figure 1 As shown in the figure, this application provides a method for detecting the mechanical state parameters of a drill string, which may include the following steps:

[0031] Step 101: Divide the drill string into multiple drill string segments according to the wellbore curvature.

[0032] Borehole curvature, also known as dogleg curvature, represents the change in wellbore direction per unit length and is a crucial parameter for measuring the degree of bending of the wellbore axis in space. The value of wellbore curvature directly affects the stress state and motion behavior of the drill string within the wellbore; a larger value indicates more severe wellbore bending. Drill string segments refer to the smaller segments into which the entire drill string is divided according to predetermined rules during drill string mechanical analysis.

[0033] In wellbore trajectory analysis, an initial calculation starting point is selected from the wellhead, and a calculation window is set along the well depth direction. Taking the window from measuring point A to measuring point B as an example, the average curvature of this well section can be calculated using the standard dogleg formula based on the inclination angle and azimuth angle data at the start and end points of the window, thus reflecting the degree of wellbore curvature within this interval. Subsequently, the calculation window is gradually slid along the well depth direction, and the above calculation is repeated until the entire wellbore trajectory is covered, ultimately obtaining a series of discrete wellbore curvatures distributed along the well depth.

[0034] Optionally, the rule for dividing drill string segments is as follows: if the wellbore curvature at a certain point is less than the division threshold, the drill string within that measurement point interval is divided into a segment; if the wellbore curvature is greater than or equal to the division threshold, the segment is divided at that measurement point location, and the portion before that point is treated as an independent segment.

[0035] In one feasible implementation, when the wellbore curvature is less than a first preset curvature, the drill string is segmented according to a first preset segment length; when the wellbore curvature is greater than or equal to the first preset curvature, the drill string is segmented according to a second preset segment length, wherein the first preset segment length is greater than the second preset segment length.

[0036] The first preset curvature is a pre-defined wellbore curvature threshold used to assess the severity of wellbore curvature. When the wellbore curvature is less than this threshold, the curvature is considered mild; when it is greater than or equal to the threshold, the curvature is considered severe. For example, if the drill string is prone to fatigue damage when the wellbore curvature exceeds 5° / 30m, 5° / 30m can be set as the first preset curvature. The first preset section length can be selected within the range of 20-50m, and the second preset section length can be determined within the range of 0-10m.

[0037] Starting from the initial well depth, the wellbore curvature at each measuring point interval is checked sequentially. If the wellbore curvature is less than the first preset curvature, the drill string is segmented according to the first preset segment length. That is, starting from the current well depth, the drill string is divided into segments extending backward by one first preset segment length, and its starting and ending well depths are recorded. If the wellbore curvature is greater than or equal to the first preset curvature, the drill string is segmented according to the second preset segment length. That is, starting from the current well depth, the drill string is divided into segments extending backward by one second preset segment length, and its starting and ending well depths are recorded. The above judgment and segmentation process is repeated until the bottom of the well is covered, thus completing the segmentation of the entire drill string.

[0038] Considering the varying curvature at different locations within the wellbore, the stress state of the drill string also changes significantly. The aforementioned scheme, which divides the wellbore into sections of different lengths based on the degree of curvature, can more accurately capture these stress variations. For example, in vertical or gently deviated sections with less curvature, the drill string experiences relatively uniform stress, and using longer sections simplifies the analysis process. Conversely, in sections with greater curvature, the drill string bears a larger additional load, and using shorter sections allows for a more detailed characterization of its complex stress features, thus more accurately reflecting the actual mechanical state of different parts of the drill string.

[0039] Step 102: Calculate the initial mechanical state parameters of all drill column segments based on the mechanical state parameter model in multiple threads of the parallel architecture.

[0040] Parallel architecture is a computer system architecture that supports the simultaneous execution of multiple computational tasks. Under this architecture, multiple threads can run on different processor cores, achieving parallel computing. Based on this capability, parallel architecture can simultaneously calculate the mechanical state parameters of multiple drill string segments, thereby significantly shortening computation time and improving overall computational efficiency and processing power. The mechanical state parameter model is a mathematical model used to describe the mechanical behavior of the drill string. This model comprehensively considers factors such as the geometric parameters, material properties, and external forces acting on the drill string, and can calculate the corresponding mechanical state parameters based on known conditions. Mechanical state parameters are physical quantities that describe the stress and motion state of drill string segments downhole, including but not limited to friction, torque, hook load, and buckling critical load.

[0041] Optionally, based on the hardware resources of the parallel computing environment and the number of drill string segments, the computational tasks are reasonably allocated to multiple threads to ensure load balancing and avoid some threads being overloaded while others are idle. Each thread is assigned corresponding drill string segment data, including geometric parameters, material properties, and external forces. Then, multiple threads are started, and each thread independently calculates the initial mechanical state parameters of its assigned drill string segment based on the allocated data and the mechanical state parameter model. After all threads have completed their calculations, the initial mechanical state parameters output by each thread are collected and integrated according to the drill string sequence to obtain the final distribution of the initial mechanical state parameters for the entire drill string.

[0042] It's important to note that a second preset curvature, such as 8° / 30m, can be set as a high-priority task scheduling threshold to ensure the execution efficiency of critical computational tasks. An empty task queue is initialized for each thread to store computational tasks for the drill string segments to be processed. Then, each drill string segment is traversed sequentially, and its wellbore curvature is compared to the second preset curvature. If the wellbore curvature of a drill string segment is less than the second preset curvature, a fixed thread is selected to process the tasks for that segment according to pre-defined rules, and the tasks for that segment are added to the task queue of the selected fixed thread. If the wellbore curvature of a drill string segment is greater than or equal to the second preset curvature, the number of tasks in the task queues of all current threads is obtained. Combined with the thread's processing capacity, its load index is estimated, such as the ratio of task quantity to processing capacity. The thread with the lowest current load is then selected as the execution thread, ensuring that high-priority tasks preempt computational resources. Furthermore, a task-stealing algorithm can be incorporated, allowing each thread to steal tasks from the tail of other random threads' queues when its own task queue is empty, further improving resource utilization.

[0043] Step 103: In the event of a sudden change in downhole measurement data, determine the local abrupt change section in the drill string based on the downhole measurement data, and determine the multiple drill string sub-segments to be inverted contained in the local abrupt change section.

[0044] Downhole measurement data refers to a series of parameters reflecting downhole conditions collected during drilling using downhole instruments such as measurement while drilling (MWD) and logging while drilling (LOD), including drill pressure, inclination angle, and azimuth. The drill string section to be inverted refers to the section of the drill string located in anomaly areas downhole that requires mechanical state inversion analysis.

[0045] Optionally, the acquired raw downhole measurement data can be preprocessed, including data cleaning, filtering, and correction, to eliminate the influence of noise and outliers. Subsequently, a mutation detection algorithm is used to analyze the preprocessed data to determine if any data mutations exist. For example, a dual trigger condition can be set: a parameter mutation is identified when the drill pressure change gradient is greater than 2 kN / m, or the actual well inclination angle change exceeds 0.5°. Once a data mutation is detected, the specific well depth at which the mutation occurred is determined based on the algorithm results. A local mutation well section is defined, extending upwards and downwards by a certain distance, such as 10–50 meters, from this depth point. Furthermore, the drill string segments contained within this well section are designated as the drill string segments to be inverted for subsequent analysis and processing.

[0046] Step 104: In multiple threads of the parallel architecture, the initial mechanical state parameters of the drill column segment to be inverted are input into the inversion mechanical state parameter model to obtain the inversion mechanical state parameters output by the inversion mechanical state parameter model.

[0047] The inverse mechanical state parameter model is a mathematical model specifically designed for inverse calculations; its essence is the solution process of an inverse mechanical problem. This model takes initial mechanical state parameters as input and, through iterative and optimization algorithms, reverse-engineers the true cause most likely leading to the observed result—the inverse mechanical state parameters. The inverse mechanical state parameters are the drill string section mechanical parameters obtained after calculation using the inverse mechanical state parameter model. Compared to the initial mechanical state parameters, the inverse mechanical state parameters more closely approximate the true mechanical state of the drill string under actual well conditions, thus possessing higher reliability.

[0048] Optionally, based on the hardware resources of the parallel computing environment and the number of drill column segments to be inverted, the inversion calculation task is reasonably allocated to multiple threads. Then, each thread is started, and each thread inputs the initial mechanical state parameters of the drill column segment to be inverted into the inversion mechanical state parameter model. The model performs iterative calculations and optimizations based on the input data, gradually correcting the initial mechanical state parameters, and finally outputting inversion mechanical state parameters that are closer to the actual working conditions.

[0049] In this embodiment, the initial mechanical state parameters of all drill string segments are first calculated synchronously in multiple threads within a parallel architecture based on a mechanical state parameter model. When a parameter mutation is detected, multiple drill string segments to be inverted within the locally mutated well section are identified, and the mechanical state parameter model is invoked in the parallel architecture to quickly complete the calculation of the inverted mechanical state parameters. Compared to traditional serial calculation methods, this application, by constructing a parallel computing architecture, compresses the overall calculation time for mechanical state parameters across the entire well section from minutes to seconds, effectively meeting the needs of real-time engineering monitoring. Furthermore, this application establishes a dynamic inversion triggering mechanism, performing localized refined inversion only for sections where parameter mutations occur, significantly reducing computational resource consumption while further improving response speed and analysis efficiency.

[0050] Figure 2 The illustration schematically shows a flowchart of a method for detecting the mechanical state parameters of a drill string according to an embodiment of this application. Figure 2 As shown in this embodiment, the initial mechanical state parameters include initial friction, initial torque, initial hook load, and initial buckling critical load. The initial mechanical state parameters of all drill string segments are calculated based on the mechanical state parameter model, including:

[0051] Step 201: Calculate the initial friction of the drill string segment based on the basic friction coefficient, friction transient coefficient, drill string rotation angular velocity, and the normal pressure exerted by the drill string segment on the well wall.

[0052]

[0053] in, This represents the initial friction of the drill column section. Based on the coefficient of friction, The friction transient coefficient, The angular velocity of the drill string rotation. This refers to the positive pressure exerted on the wellbore by the drill string section.

[0054] The above formula introduces the time derivative of the rotational angular velocity. By considering the dynamic correction of the friction coefficient, the friction hysteresis problem when the rotational speed changes abruptly in the traditional model is solved.

[0055] Step 202: Calculate the initial torque of the drill string segment based on the equivalent radius of the drill string segment, the tangential force of the drill string segment, the torque-curvature coupling factor, the bending stiffness of the drill string, the section rotation angle, and the arc length along the drill string axis.

[0056]

[0057] in, This represents the initial torque for drilling the column section. Let be the equivalent radius of the drilled column segment. The tangential force is the force applied to the drilled column section. The torque curvature coupling factor. For the bending stiffness of the drill string, For the cross-sectional angle, It is the arc length along the drill string axis.

[0058] The above formula introduces a torque curvature coupling factor. This study revealed the interaction mechanism between torque and wellbore curvature, thereby significantly improving the accuracy of torque calculation in curved well sections.

[0059] Step 203: Calculate the initial hook load of the drill string segment based on the initial hook load, the frictional resistance of the drill string segment, the rotational angular velocity of the drill string, and the axial displacement.

[0060]

[0061] in, The initial hook load for drilling the column section. Initial hook load for the drill string, The frictional resistance of the drill column section. The angular velocity of the drill string rotation. This represents axial displacement.

[0062] The above formula introduces an axial acceleration term. This effectively corrects the hook load calculation during dynamic drilling.

[0063] Step 204: Calculate the initial buckling critical load of the drill string segment based on the drill string bending stiffness, length coefficient, length of the drill string segment, and initial torque of the drill string segment.

[0064]

[0065] in, This represents the initial buckling critical load of the drill string segment. For the bending stiffness of the drill string, This is the length coefficient. The length of the drilled column section. This represents the initial buckling critical load of the drill string segment.

[0066] The above formula, by introducing a torque correction term, considers the influence of torque on the critical buckling load, thus solving the defect of the traditional Euler formula that ignores torque coupling.

[0067] It should be noted that it can also be based on the well inclination change rate. The system automatically matches a suitable mechanical model to each drill string segment for calculating torque-related parameters, such as... Figure 3 As shown. The specific steps are as follows:

[0068] First, a numerical differential method is used to calculate the wellbore inclination rate based on the wellbore curvature of two adjacent measuring points. Subsequently, the calculated well inclination change rate was... Compare with the first preset rate of change and the second preset rate of change, such as the first preset rate of change being taken as... The second preset rate of change is 1. .

[0069] If the rate of change of well inclination is less than the first preset rate of change, that is When using the rigid bar model:

[0070]

[0071] in, This represents the change in torque during drilling of the column section. The initial hook load for drilling the column section. The well inclination angle, The coefficient of friction, The drill string rotation phase angle, For the bending stiffness of the drill string, The angle of rotation of the cross section.

[0072] If the well inclination change rate is greater than the second preset change rate, that is Enable flexible rod model at this time:

[0073]

[0074] in, The bending moment of the drill column section. The arc length along the drill string axis, For wellbore curvature, This represents the initial torque for drilling the column section. For normal constraint force, Mass per unit length of drill string This is the fluid resistance coefficient. The well inclination angle, This represents the rate of change of well inclination.

[0075] If the well inclination rate is greater than or equal to the first preset rate of change and less than or equal to the second preset rate of change, that is... In the transition zone, a weighted fusion model is adopted:

[0076]

[0077] in, For the fusion torque of the drill column section, The preset weights can be fixed values ​​or based on a formula. calculate, The output result for the flexible rod model is... , Output the results for the rigid bar model, i.e. .

[0078] In this embodiment, by comprehensively utilizing rigid rod models, flexible rod models, and weighted fusion models, it is possible to select appropriate mechanical models for calculation based on different well deviation rate conditions, fully leverage the advantages of each model, improve the accuracy and reliability of drill string mechanical analysis, and provide strong support for the safe and efficient conduct of drilling projects.

[0079] Figure 4 The illustration schematically shows a flowchart of a method for detecting the mechanical state parameters of a drill string according to an embodiment of this application. Figure 4 As shown in this embodiment, the initial mechanical state parameters include initial friction, initial torque, and initial hook load. The inversion mechanical state parameters include inversion friction, inversion torque, inversion hook load, and hook load at the wellhead. The initial mechanical state parameters of the drill string segment to be inverted are input into the inversion mechanical state parameter model to obtain the inversion mechanical state parameters output by the inversion mechanical state parameter model, including:

[0080] Step 401: Calculate the friction increment of the drill string segment to be inverted based on static friction, torque axial gradient coefficient, initial torque of the drill string segment to be inverted, arc length along the drill string axis, and time-varying attenuation coefficient.

[0081] Step 402: Based on the friction increment of the drill string segment to be inverted and the time step, update the initial friction of the drill string segment to be inverted to obtain the inverted friction of the drill string segment to be inverted.

[0082] First, considering the effects of static friction, torque gradient, and time-varying attenuation due to wellbore damping, the friction change during the dynamic process is accurately described. The specific formula is as follows:

[0083]

[0084] in, The friction increment of the drill column segment to be inverted, Static friction, The axial gradient coefficient of torque. This represents the initial torque for drilling the column section. The arc length along the drill string axis, This refers to the gradient of torque along the well depth direction. This is the time-varying decay coefficient.

[0085] Then, the friction of the inverted drill string segment is explicitly updated using the calculated friction increment. The specific formula is as follows:

[0086]

[0087] in, To determine the inversion friction of the drill column segment to be inverted, The initial friction of the drill column segment to be inverted. The friction increment of the drill column segment to be inverted, For time step.

[0088] Step 403: Based on the initial torque of the lower end face of the drill string segment to be inverted, the equivalent radius of the drill string segment to be inverted, the inversion friction of the drill string segment to be inverted, the sign function of the rotation direction, the torque curvature coupling factor, the bending stiffness of the drill string, the section rotation angle, and the arc length along the drill string axis, the inversion torque of the upper end face of the drill string segment to be inverted is obtained.

[0089] Given that the torque is transmitted from bottom to top along the drill string, its variation within any segment is... This is primarily caused by the tangential friction of this segment. Torque updates follow the integration sequence from the bottom of the well to the wellhead. For any inverted drill string segment within a locally abruptly changed well section... Torque at its lower end face Given (calculation results or boundary conditions from the lower segment), then the torque on its upper end face... The updated formula is:

[0090]

[0091] in, The inversion torque is the torque at the upper end of the drill string section to be inverted, i.e., the hook load at the wellhead. The initial torque at the lower end face of the drill string segment to be inverted is given. To determine the equivalent radius of the drill string segment, To determine the inversion friction of the drill column segment to be inverted, The sign function for the direction of rotation. The torque curvature coupling factor. For the bending stiffness of the drill string, For the cross-sectional angle, The arc length along the drill string axis, That is, curvature.

[0092] Step 404: Based on the initial hook load of the drill string segment to be inverted, the friction increment of the drill string segment to be inverted, and the rotation direction sign function, the inversion hook load of the drill string segment to be inverted is obtained.

[0093] Step 405: Based on the axial force on the upper end face of the drill string segment to be inverted, the inversion friction of the drill string segment to be inverted, the sign function of the rotation direction, the buoyancy per unit length of the drill string in the drilling fluid, the gravitational acceleration, the length of the drill string segment to be inverted, the well inclination angle of the drill string segment to be inverted, the angular velocity of the drill string rotation, and the axial acceleration of the drill string segment to be inverted, the hook load at the wellhead of the drill string segment to be inverted is obtained.

[0094] In local inversion, since only the friction of a portion of the well section is updated, the update amount of the global hook load is the accumulation of the axial force change caused by the friction change of the local well section.

[0095]

[0096] in, For the inversion hook load of the drill column segment to be inverted, The initial hook load for the drill column segment to be inverted. To determine the inversion friction of the drill column segment to be inverted, The initial friction of the drill column segment to be inverted. This is a sign function for the axial motion direction.

[0097] The hook load at the wellhead is the axial force on the upper end face of the top section of the drill string. .

[0098]

[0099] in, The axial force on the lower end face of the drill string segment to be inverted is... The axial force on the upper end face of the drill string segment to be inverted is... To determine the inversion friction of the drill column segment to be inverted, The sign function for the axial motion direction. This is the buoyancy of the drill string per unit length in the drilling fluid. It is the acceleration due to gravity. The length of the drill column segment to be inverted. The well inclination angle of the drill string section to be inverted. The angular velocity of the drill string rotation. The value represents the axial acceleration of the drill string segment to be inverted.

[0100] It is important to note that after obtaining the inverted mechanical state parameters, the changes in friction between the initial and inverted friction, the changes in torque between the initial and inverted torque, and the changes in hook load between the initial and inverted hook load can be further calculated. Then, the maximum change among these three can be determined. If this maximum change does not reach a preset tolerance threshold, such as 0.001, it indicates that the inversion result has converged, and the loop should be exited. If the maximum change does not reach the preset tolerance threshold, it indicates that the inversion result has not converged, and the time step should be updated. The specific formula is as follows:

[0101]

[0102] in, For the updated time step, The time step before the update. To preset the tolerance threshold, This represents the maximum value of the friction increment of the drill string segment to be inverted.

[0103] At the new time step, the above inversion steps are iterated until the preset tolerance threshold is reached.

[0104] After the iteration converges, high-precision inverted mechanical state parameters of the local well section are output, and a safety assessment is performed based on these results. For example, when the buckling risk coefficient... hour( This is the actual axial load. (For the buckling critical load), a red alert will be triggered, and the real-time calculation results will be output and displayed to achieve dynamic monitoring and risk warning of the wellbore status.

[0105] For example, in a well with a drilling depth of 4000m, the build-up section (2000-3500m) has a large dogleg degree. After system initialization, parallel modeling and calculation of the entire well section are performed first. During drilling, when the system detects a sudden change in the drill pressure gradient of 3kN / m at 2510m (exceeding the 2kN / m threshold), a dynamic inversion mechanism is immediately triggered. The system only initiates local GPU parallel calculation for the 2500-2520m section, using an adaptive step-size improved Euler method to quickly update the friction and torque of this section. Simultaneously, based on the well inclination change rate Ka=0.8° / m for this section, the system automatically uses the weighted fusion result of the soft rod and rigid rod models (η=tan(0.8)≈0.72). The entire local inversion process takes only 3.2 seconds, and the calculation results are displayed in real time. When the system calculates the buckling risk coefficient Rb to rise to 0.85, a red alert is immediately sent to the well control center, guiding engineers to adjust the drill pressure in a timely manner, successfully avoiding a potential buckling accident.

[0106] For reference Figure 5 This is a comparison of the computational performance of different well sections.

[0107] Figure 1 This is a flowchart illustrating a method for detecting the mechanical state parameters of a drill string in one embodiment. It should be understood that, although... Figure 1 The steps in the flowchart are shown sequentially as indicated by the arrows, but these steps are not necessarily executed in the order indicated by the arrows. Unless otherwise explicitly stated herein, there is no strict order in which these steps are executed, and they can be performed in other orders. Figure 1 At least some of the steps in the process may include multiple sub-steps or multiple stages. These sub-steps or stages are not necessarily completed at the same time, but can be executed at different times. The execution order of these sub-steps or stages is not necessarily sequential, but can be executed in turn or alternately with other steps or at least some of the sub-steps or stages of other steps.

[0108] In one embodiment, such as Figure 6 As shown, a mechanical state parameter detection device 600 for a drill string is provided, including a drill string segment division module, an initial mechanical state parameter calculation module, a drill string segment determination module to be inverted module, and an inversion mechanical state parameter calculation module, wherein:

[0109] The drill string segment division module 601 is used to divide the drill string into multiple drill string segments according to the wellbore curvature.

[0110] The initial mechanical state parameter calculation module 602 is used to calculate the initial mechanical state parameters of all drill column segments based on the mechanical state parameter model in multiple threads of a parallel architecture.

[0111] The drill string segment determination module 603 is used to determine the local abrupt change segment in the drill string based on the downhole measurement data when a sudden change is detected in the downhole measurement data, and to determine the multiple drill string segments to be inverted contained in the local abrupt change segment.

[0112] The inversion mechanical state parameter calculation module 604 is used to input the initial mechanical state parameters of the drill column segment to be inverted into the inversion mechanical state parameter model in multiple threads of the parallel architecture, so as to obtain the inversion mechanical state parameters output by the inversion mechanical state parameter model.

[0113] The drill string mechanical state parameter detection device includes a processor and a memory. The drill string segment division module, the initial mechanical state parameter calculation module, the drill string segment determination module to be inverted module, and the inversion mechanical state parameter calculation module are all stored as program units in the memory. The processor executes the above program modules stored in the memory to implement the corresponding functions.

[0114] The processor contains a kernel, which retrieves the corresponding program units from memory. One or more kernels can be configured, and adjusting the kernel parameters enables methods for detecting the mechanical state parameters of the drill string.

[0115] The memory may include non-permanent memory in computer-readable media, such as random access memory (RAM) and / or non-volatile memory, such as read-only memory (ROM) or flash RAM, and the memory includes at least one memory chip.

[0116] This application provides a storage medium storing a program that, when executed by a processor, implements the above-described method for detecting the mechanical state parameters of a drill string.

[0117] This application provides a processor for running a program, wherein the program executes the above-described method for detecting the mechanical state parameters of a drill string.

[0118] In one embodiment, a computer device is provided, which may be a server, and its internal structure diagram may be as follows: Figure 7 As shown. The computer device includes a processor A01, a network interface A02, a memory (not shown), and a database (not shown) connected via a system bus. The processor A01 provides computational and control capabilities. The memory includes internal memory A03 and a non-volatile storage medium A04. The non-volatile storage medium A04 stores an operating system B01, a computer program B02, and a database (not shown). The internal memory A03 provides an environment for the operation of the operating system B01 and the computer program B02 in the non-volatile storage medium A04. The database stores information such as wellbore curvature. The network interface A02 communicates with external terminals via a network connection. When executed by the processor A01, the computer program B02 implements a method for detecting the mechanical state parameters of a drill string.

[0119] Those skilled in the art will understand that Figure 7 The structure shown is merely a block diagram of a portion of the structure related to the present application and does not constitute a limitation on the computer device to which the present application is applied. Specific computer devices may include more or fewer components than those shown in the figure, or combine certain components, or have different component arrangements.

[0120] This application provides a computer (electronic) device, which includes a processor, a memory, and a program stored in the memory and executable on the processor. When the processor executes the program, it implements the steps of any of the above-mentioned methods for detecting the mechanical state parameters of a drill string.

[0121] This application also provides a computer program product that, when executed on a data processing device, is suitable for performing the steps of a method for initializing the mechanical state parameter detection of a drill string.

[0122] Those skilled in the art will understand that embodiments of this application can be provided as methods, systems, or computer program products. Therefore, this application can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, this application can take the form of a computer program product embodied on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0123] This application is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of this application. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, generate instructions for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0124] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0125] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.

[0126] In a typical configuration, a computing device includes one or more processors (CPU), input / output interfaces, network interfaces, and memory.

[0127] Memory may include non-persistent memory in computer-readable media, such as random access memory (RAM) and / or non-volatile memory, such as read-only memory (ROM) or flash RAM. Memory is an example of computer-readable media.

[0128] Computer-readable media includes both permanent and non-permanent, removable and non-removable media that can store information using any method or technology. Information can be computer-readable instructions, data structures, modules of programs, or other data. Examples of computer storage media include, but are not limited to, phase-change memory (PRAM), static random access memory (SRAM), dynamic random access memory (DRAM), other types of random access memory (RAM), read-only memory (ROM), electrically erasable programmable read-only memory (EEPROM), flash memory or other memory technologies, CD-ROM, digital versatile optical disc (DVD) or other optical storage, magnetic tape, magnetic disk storage or other magnetic storage devices, or any other non-transferable medium that can be used to store information accessible by a computing device. As defined herein, computer-readable media does not include transient computer-readable media, such as modulated data signals and carrier waves.

[0129] It should also be noted that the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such process, method, article, or apparatus. Unless otherwise specified, an element defined by the phrase "comprising one..." does not exclude the presence of other identical elements in the process, method, article, or apparatus that includes that element.

[0130] The above are merely embodiments of this application and are not intended to limit the scope of this application. Various modifications and variations can be made to this application by those skilled in the art. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of this application should be included within the scope of the claims of this application.

Claims

1. A method for detecting the mechanical state parameters of a drill string, characterized in that, The method includes: The drill string is divided into multiple drill string segments based on the wellbore curvature; In multiple threads of a parallel architecture, the initial mechanical state parameters of all drill string segments are calculated based on a mechanical state parameter model. In the event of a sudden change in downhole measurement data, the local abrupt change section in the drill string is determined based on the downhole measurement data, and multiple drill string segments to be inverted are identified within the local abrupt change section. In multiple threads of the parallel architecture, the initial mechanical state parameters of the drill column segment to be inverted are input into the inversion mechanical state parameter model to obtain the inversion mechanical state parameters output by the inversion mechanical state parameter model. The drill string is divided into multiple segments based on the wellbore curvature, including: If the wellbore curvature is less than the first preset curvature, the drill string is segmented according to the first preset segment length; When the wellbore curvature is greater than or equal to the first preset curvature, the drill string is segmented according to the second preset segment length, wherein the first preset segment length is greater than the second preset segment length; The initial mechanical state parameters include initial friction, initial torque, initial hook load, and initial buckling critical load. The initial mechanical state parameters for all drill string segments are calculated based on the mechanical state parameter model, including: The initial friction of the drill string section is calculated based on the basic friction coefficient, friction transient coefficient, drill string rotation angular velocity, and the normal pressure exerted on the well wall by the drill string section. The initial torque of the drill string segment is calculated based on the equivalent radius of the drill string segment, the tangential force of the drill string segment, the torque-curvature coupling factor, the bending stiffness of the drill string, the section rotation angle, and the arc length along the drill string axis. The initial hook load of the drill string segment is calculated based on the initial hook load of the drill string, the frictional resistance of the drill string segment, the rotational angular velocity of the drill string, and the axial displacement. The initial buckling critical load of the drill string segment is calculated based on the drill string bending stiffness, length coefficient, length of the drill string segment, and initial torque of the drill string segment.

2. The method for detecting the mechanical state parameters of a drill string according to claim 1, characterized in that, The method further includes: If the wellbore curvature of the drill string section is less than the second preset curvature, a corresponding fixed thread is selected; When the wellbore curvature of the drill string section is greater than or equal to the second preset curvature, the corresponding thread is dynamically selected based on the number of tasks in the task queue of all threads.

3. The method for detecting the mechanical state parameters of a drill string according to claim 1, characterized in that, The method further includes: Determine the rate of change of well inclination for the drill string section; When the well inclination change rate is less than or equal to the first preset change rate, the torque change of the drill string segment is calculated based on the wellbore curvature, the initial friction of the drill string segment, the normal constraint force, the mass per unit length of the drill string, the fluid resistance coefficient, and the well inclination change rate. When the well inclination change rate is greater than the second preset change rate, the bending moment of the drill string segment is calculated based on the initial hook load of the drill string segment, the well inclination angle of the drill string segment, the friction coefficient, the rotation phase angle of the drill string, the bending stiffness of the drill string, the section rotation angle, and the arc length along the drill string axis. The first preset change rate is less than the second preset change rate. When the well inclination change rate is greater than the first preset change rate and less than or equal to the second preset change rate, the bending moment and the moment change amount are weighted according to preset weights to obtain the fusion moment of the drill string segment.

4. The method for detecting the mechanical state parameters of a drill string according to claim 1, characterized in that, The initial mechanical state parameters include initial friction, initial torque, and initial hook load. The inversion mechanical state parameters include inversion friction, inversion torque, inversion hook load, and hook load at the wellhead. The initial mechanical state parameters of the drill string segment to be inverted are input into the inversion mechanical state parameter model to obtain the inversion mechanical state parameters output by the inversion mechanical state parameter model, including: The friction increment of the drill string segment to be inverted is calculated based on static friction, torque axial gradient coefficient, initial torque of the drill string segment to be inverted, arc length along the drill string axis, and time-varying attenuation coefficient. Based on the friction increment of the drill string segment to be inverted and the time step, the initial friction of the drill string segment to be inverted is updated to obtain the inversion friction of the drill string segment to be inverted. The inversion torque of the upper end face of the drill string segment to be inverted is obtained based on the initial torque of the lower end face of the drill string segment to be inverted, the equivalent radius of the drill string segment to be inverted, the inversion friction of the drill string segment to be inverted, the sign function of the rotation direction, the torque curvature coupling factor, the bending stiffness of the drill string, the section rotation angle, and the arc length along the drill string axis. Based on the initial hook load of the drill string segment to be inverted, the friction increment of the drill string segment to be inverted, and the sign function of the rotation direction, the inversion hook load of the drill string segment to be inverted is obtained. Based on the axial force on the upper end face of the drill string segment to be inverted, the inversion friction of the drill string segment to be inverted, the sign function of the rotation direction, the buoyancy per unit length of the drill string in the drilling fluid, the gravitational acceleration, the length of the drill string segment to be inverted, the well inclination angle of the drill string segment to be inverted, the angular velocity of the drill string rotation, and the axial acceleration of the drill string segment to be inverted, the hook load at the wellhead of the drill string segment to be inverted is obtained.

5. The method for detecting the mechanical state parameters of a drill string according to claim 4, characterized in that, The method further includes: Calculate the frictional change between the initial frictional resistance and the inverted frictional resistance, the torque change between the initial torque and the inverted torque, and the hook load change between the initial hook load and the inverted hook load; If the maximum value among the friction change, torque change, and hook load change does not reach a preset tolerance threshold, the time step is updated based on the preset tolerance threshold and the friction increment. Jump to the step of calculating the friction increment of the drill string segment to be inverted based on static friction, torque axial gradient coefficient, initial torque of the drill string segment to be inverted, arc length along the drill string axis, and time-varying attenuation coefficient.

6. A device for detecting the mechanical state parameters of a drill string, characterized in that, include: The memory is configured to store instructions; The processor is configured to retrieve the instructions from the memory and, when executing the instructions, to implement the method for detecting the mechanical state parameters of the drill string according to any one of claims 1 to 5.

7. A device for detecting the mechanical state parameters of a drill string, characterized in that, include: The mechanical state parameter detection device for drill string according to claim 6.

8. A machine-readable storage medium storing instructions thereon, characterized in that, When executed by a processor, this instruction causes the processor to be configured to perform a method for detecting the mechanical state parameters of a drill string according to any one of claims 1 to 5.

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