A method for analyzing the mechanical behavior of bias force of drilling steering tools

Abstract

The present invention discloses a method for analyzing the mechanical behavior of the bias force of a drilling steering tool. The method comprises: establishing a wellbore trajectory coordinate data matrix based on drilling wellbore trajectory data; calculating the wellbore inclination change rate and the azimuth change rate of each wellbore trajectory coordinate node corresponding to the wellbore trajectory coordinate data based on the wellbore trajectory coordinate data in the wellbore trajectory coordinate data matrix; and performing vector synthesis of the magnitude and direction of the drilling steering tool bias force required for each wellbore trajectory coordinate node based on the wellbore trajectory change rate, the azimuth change rate and the maximum drilling steering tool fluid pressure of each wellbore trajectory coordinate node. The method for analyzing the mechanical behavior of the bias force of a drilling steering tool disclosed in the present invention can perform mechanical behavior analysis on the drilling steering tool during the drilling process, and visually display the magnitude and direction of the bias force of the drilling steering tool at each wellbore trajectory coordinate node during the drilling process.

Description

Technical Field

[0001] The present invention relates to the field of oil drilling engineering technology and equipment, and in particular to a method for analyzing the mechanical behavior of a drilling steering tool bias force. Background Art

[0002] In the oil and gas sector, advancements in drilling technology have led to an increasing number of directional, horizontal, and branch wells being drilled. Wellbore trajectory design has become increasingly complex, and the requirements for precise trajectory control during drilling have also increased. Currently, wellbore trajectory control during drilling primarily relies on the experience of surface personnel. After drilling is complete, there is a lack of intelligent methods for analyzing and summarizing the mechanical control schemes for the drilled wellbore trajectory. This makes it impossible to analyze and summarize the mechanical behavior of the drilling steerable tool during drilling on a timescale, limiting the further development of intelligent drilling technology. Summary of the Invention

[0003] In order to solve the above problems, the present invention proposes a mechanical behavior analysis method for the bias force of a drilling steering tool, which visualizes and digitizes the bias force generated by the intelligent drilling steering tool during the wellbore trajectory control process, provides data support for the design of the drilling steering bias force in the same block formation, and provides a drilling case analysis method for the intelligent drilling wellbore trajectory control technology.

[0004] In view of the above problems, the present invention is proposed to provide a method for analyzing the mechanical behavior of the bias force of a drilling steering tool, which overcomes the above problems or at least partially solves the above problems.

[0005] In a first aspect, an embodiment of the present invention provides a method for analyzing the mechanical behavior of a drilling steering tool bias force, comprising:

[0006] Establishing a wellbore trajectory coordinate data matrix based on drilling wellbore trajectory data;

[0007] Calculating the inclination angle change rate and the azimuth angle change rate of each wellbore trajectory coordinate node corresponding to the wellbore trajectory coordinate data according to the wellbore trajectory coordinate data in the wellbore trajectory coordinate data matrix;

[0008] According to the inclination change rate, azimuth change rate and maximum drilling steering tool hydraulic pressure of each wellbore trajectory coordinate node, the magnitude and direction of the drilling steering tool bias force required by each wellbore trajectory coordinate node are vector-synthesized.

[0009] In one embodiment, establishing a wellbore trajectory coordinate data matrix based on drilling wellbore trajectory data includes:

[0010] According to the first well inclination, first azimuth and well depth data corresponding to each well trajectory coordinate node in the drilling well trajectory data, the well trajectory coordinate data matrix in the Cartesian coordinate system is established by applying the cylindrical spiral method and the three-dimensional data difference method.

[0011] In one embodiment, based on the first well inclination angle, the first azimuth angle, and the well depth data corresponding to each well trajectory coordinate node in the drilling well trajectory data, a cylindrical spiral method and a three-dimensional data interpolation method are applied to establish a well trajectory coordinate data matrix in a Cartesian coordinate system, including:

[0012] According to the first well inclination angle, the first azimuth angle and the well depth data corresponding to each well trajectory coordinate node in the drilling well trajectory data, the cylindrical spiral method is applied to calculate and obtain the pre-processed coordinate data corresponding to each well trajectory coordinate node;

[0013] According to the pre-processed coordinate data corresponding to each wellbore trajectory coordinate node, the wellbore trajectory coordinate data corresponding to each wellbore trajectory coordinate node is calculated by applying a three-dimensional data difference method;

[0014] A wellbore trajectory coordinate data matrix in a Cartesian coordinate system is established based on the wellbore trajectory coordinate data corresponding to each wellbore trajectory coordinate node obtained by the calculation.

[0015] In one embodiment, calculating the well inclination angle change rate of each well trajectory coordinate node corresponding to the well trajectory coordinate data based on the well trajectory coordinate data in the well trajectory coordinate data matrix includes:

[0016] Calculating a second well inclination angle of each well trajectory coordinate node corresponding to the well trajectory coordinate data using a well inclination angle calculation formula according to the well trajectory coordinate data in the well trajectory coordinate data matrix;

[0017] According to the second well inclination angle of each wellbore trajectory coordinate node, the well inclination angle change rate of each wellbore trajectory coordinate node is calculated using the well inclination angle change rate calculation formula.

[0018] In one embodiment, the well inclination angle calculation formula is:

[0019]

[0020] In the above formula, i represents the order of each wellbore trajectory coordinate node, x and z represent the x-axis coordinate and z-axis coordinate of the wellbore trajectory coordinate data corresponding to each wellbore trajectory coordinate node;

[0021] The calculation formula for the well inclination angle change rate is:

[0022]

[0023] In the above formula, i represents the order of each wellbore trajectory coordinate node.

[0024] In one embodiment, calculating the azimuth change rate of each wellbore trajectory coordinate node corresponding to the wellbore trajectory coordinate data based on the wellbore trajectory coordinate data in the wellbore trajectory coordinate data matrix includes:

[0025] Calculating the second azimuth angle of each wellbore trajectory coordinate node corresponding to the wellbore trajectory coordinate data using an azimuth angle calculation formula according to the wellbore trajectory coordinate data in the wellbore trajectory coordinate data matrix;

[0026] According to the second azimuth of each wellbore trajectory coordinate node, the azimuth change rate of each wellbore trajectory coordinate node is calculated using the azimuth change rate calculation formula.

[0027] In one embodiment, the azimuth angle calculation formula is:

[0028]

[0029] In the above formula, i represents the order of each wellbore trajectory coordinate node, x and y represent the x-axis coordinate and y-axis coordinate of the wellbore trajectory coordinate data corresponding to each wellbore trajectory coordinate node;

[0030] The calculation formula for the azimuth angle change rate is:

[0031]

[0032] In the above formula, i represents the order of each wellbore trajectory coordinate node.

[0033] In one embodiment, vector synthesis of the magnitude and direction of the drilling steering tool bias force required for each wellbore trajectory coordinate node is performed based on the wellbore trajectory coordinate node's inclination angle change rate, azimuth angle change rate, and maximum drilling steering tool hydraulic pressure, including:

[0034] Calculating the deflection bias force corresponding to each wellbore trajectory coordinate node using a deflection bias force calculation formula based on the well inclination angle change rate of each wellbore trajectory coordinate node and the maximum drilling steering tool fluid pressure;

[0035] Calculating the azimuth bias force corresponding to each wellbore trajectory coordinate node using an azimuth bias force calculation formula based on the azimuth angle change rate of each wellbore trajectory coordinate node and the maximum drilling steering tool fluid pressure;

[0036] Based on the deflection bias force and azimuth bias force corresponding to each wellbore trajectory coordinate node, the magnitude of the drilling steering tool bias force required by each wellbore trajectory coordinate node is synthesized using a bias force resultant magnitude calculation formula;

[0037] The directions of the drilling steering tool bias forces required for the respective wellbore trajectory coordinate nodes are synthesized using a bias force resultant direction calculation formula based on the wellbore trajectory coordinate data corresponding to the respective wellbore trajectory coordinate nodes.

[0038] In one embodiment, the formula for calculating the deflection bias force is:

[0039]

[0040] In the above formula, dA devi is the rate of change of well inclination, dA max F is the maximum value of the drilling steering tool deflection angle, max is the maximum fluid pressure of the drilling steering tool;

[0041] The calculation formula for the azimuth bias force is:

[0042]

[0043] In the above formula, dA ori is the azimuth angle change rate, dA max F is the maximum value of the drilling steering tool deflection angle, max is the maximum fluid pressure of the drilling steering tool;

[0044] The calculation formula for the resultant bias force is:

[0045]

[0046] In the above formula, F devi is the deflection bias force, F ori To create azimuth bias force;

[0047] The formula for calculating the direction of the resultant bias force is:

[0048]

[0049]

[0050] In the above formula, represents the drilling direction vector, represents the bias force direction vector of the drilling steering tool, and x, y, and z represent the x-axis coordinate, y-axis coordinate, and z-axis coordinate of the wellbore trajectory coordinate data corresponding to each wellbore trajectory coordinate node.

[0051] In one embodiment, after vector synthesis of the magnitude and direction of the drilling steering tool bias force required for each wellbore trajectory coordinate node based on the wellbore trajectory change rate, azimuth change rate, and maximum drilling steering tool hydraulic pressure at each wellbore trajectory coordinate node, the method further includes:

[0052] According to each wellbore trajectory coordinate node, in the preset three-dimensional display diagram data, the drilling steering tool bias force required for each wellbore trajectory coordinate node synthesized by vector is associated with the said each wellbore trajectory coordinate node and displayed through the said three-dimensional display diagram.

[0053] In a second aspect, an embodiment of the present invention provides a wellbore trajectory control method for controlling the trajectory of a drilling wellbore based on vector data of the steering tool bias force obtained by the aforementioned drilling steering tool bias force mechanical behavior analysis method.

[0054] In a third aspect, an embodiment of the present invention provides a device for analyzing the mechanical behavior of a drilling steering tool bias force, comprising:

[0055] An establishment module for establishing a wellbore trajectory coordinate data matrix based on drilling wellbore trajectory data;

[0056] a calculation module for calculating, based on the wellbore trajectory coordinate data in the wellbore trajectory coordinate data matrix, a well inclination angle change rate and an azimuth angle change rate of each wellbore trajectory coordinate node corresponding to the wellbore trajectory coordinate data;

[0057] The synthesis module is used to perform vector synthesis on the magnitude and direction of the drilling steering tool bias force required for each wellbore trajectory coordinate node according to the well inclination angle change rate, azimuth angle change rate and maximum drilling steering tool fluid pressure of each wellbore trajectory coordinate node.

[0058] In a fourth aspect, an embodiment of the present invention provides a computer-readable storage medium storing a computer program, which, when executed by a processor, implements the aforementioned method for analyzing the mechanical behavior of the bias force of a drilling guide tool.

[0059] In a fifth aspect, an embodiment of the present invention provides a computer program product, which includes a computer program. When the computer program is executed by a processor, it implements the aforementioned method for analyzing the mechanical behavior of the bias force of a drilling guide tool.

[0060] The beneficial effects of the above technical solutions provided by the embodiments of the present invention include at least:

[0061] The embodiments of the present invention provide a drilling steering tool bias force mechanical behavior analysis method and a wellbore trajectory control method, which establish a wellbore trajectory coordinate data matrix based on drilling wellbore trajectory data; calculate the wellbore trajectory coordinate data in the wellbore trajectory coordinate data according to the wellbore trajectory coordinate data, and the wellbore trajectory coordinate data corresponding to each wellbore trajectory coordinate node. According to the wellbore trajectory coordinate data in the wellbore trajectory coordinate data matrix, the wellbore inclination angle change rate and the azimuth angle change rate of each wellbore trajectory coordinate node are calculated; according to the wellbore trajectory coordinate data, the wellbore trajectory coordinate data, the magnitude and direction of the drilling steering tool bias force required for each wellbore trajectory coordinate node are vector synthesized; by processing the wellbore trajectory data and performing a mechanical behavior analysis on the drilling steering tool during the drilling process, data can be provided for the research and development of intelligent wellbore trajectory control technology, and basic data and analysis means can be provided for the coupling study of the steering tool deflection force and the drillability of the formation, so as to improve the control accuracy of the wellbore trajectory.

[0062] The mechanical behavior analysis method of the drilling steering tool bias force provided in an embodiment of the present invention also visualizes the wellbore trajectory control process, and can visually display the magnitude and direction of the bias force of the drilling steering tool at each wellbore trajectory coordinate node during the actual drilling wellbore trajectory, providing an analysis basis for ground steering personnel to optimize the wellbore trajectory control process, which not only makes manual error correction and improves the trajectory correction process more convenient, but also provides a technical foundation for future wellbore trajectory closed-loop control.

[0063] Other features and advantages of the present invention will be described in the following description, and in part will become apparent from the description, or will be understood by practicing the present invention. The purposes and other advantages of the present invention can be realized and obtained by the structures particularly pointed out in the written description, claims, and drawings.

[0064] The technical solution of the present invention is further described in detail below through the accompanying drawings and embodiments. BRIEF DESCRIPTION OF THE DRAWINGS

[0065] The accompanying drawings are used to provide a further understanding of the present invention and constitute a part of the specification. Together with the embodiments of the present invention, they are used to explain the present invention and do not constitute a limitation of the present invention. In the accompanying drawings:

[0066] Figure 1 This is a flow chart of a method for analyzing the mechanical behavior of a drilling steering tool bias force according to an embodiment of the present invention;

[0067] Figure 2 Schematic diagram of a wellbore trajectory coordinate data matrix according to an embodiment of the present invention;

[0068] Figure 3 Schematic diagram of the bias force of the drilling steering tool at some wellbore trajectory coordinate nodes in an embodiment of the present invention;

[0069] Figure 4 Schematic diagram of the bias force of the drilling steering tool on the tool face at some time nodes in an embodiment of the present invention;

[0070] Figure 5 4 is a structural block diagram of a drilling steering tool bias force mechanical behavior analysis device in an embodiment of the present invention. DETAILED DESCRIPTION

[0071] Exemplary embodiments of the present disclosure will be described in more detail below with reference to the accompanying drawings. Although exemplary embodiments of the present disclosure are shown in the accompanying drawings, it should be understood that the present disclosure can be implemented in various forms and should not be limited by the embodiments set forth herein. Rather, these embodiments are provided to enable a more thorough understanding of the present disclosure and to fully convey the scope of the present disclosure to those skilled in the art.

[0072] In order to better realize the mechanical behavior analysis of the bias force generated by the drilling steering tool during the drilling process, the embodiment of the present invention provides a drilling steering tool bias force mechanical behavior analysis method, referring to Figure 1 As shown, the method includes the following steps:

[0073] S11, establishing a wellbore trajectory coordinate data matrix based on the drilling wellbore trajectory data;

[0074] S12, calculating the wellbore trajectory coordinate data in the wellbore trajectory coordinate data matrix, the wellbore trajectory coordinate data corresponding to each wellbore trajectory coordinate node's inclination angle change rate and azimuth angle change rate;

[0075] S13. Perform vector synthesis of the magnitude and direction of the drilling steering tool bias force required for each wellbore trajectory coordinate node based on the wellbore trajectory change rate, azimuth change rate, and maximum drilling steering tool hydraulic pressure of each wellbore trajectory coordinate node.

[0076] In the embodiment of the present invention, the drilling steering tool bias force refers to a lateral force provided by a static bias mechanism in a fixed direction without rotating together with the drill string during drilling.

[0077] The method for analyzing the mechanical behavior of the bias force of a drilling steering tool provided in an embodiment of the present invention calculates the wellbore trajectory coordinate data corresponding to each wellbore trajectory coordinate node in the wellbore trajectory based on the drilling wellbore trajectory data generated during the actual drilling process, and establishes a wellbore trajectory coordinate data matrix based on the wellbore trajectory coordinate data corresponding to each wellbore trajectory coordinate node, such as Figure 2As shown, the wellbore trajectory coordinate data matrix records the wellbore trajectory coordinate data corresponding to each wellbore trajectory coordinate node. Based on the above wellbore trajectory coordinate data, the wellbore inclination angle change rate and the azimuth angle change rate of each wellbore trajectory coordinate node can be calculated; then, based on the wellbore trajectory coordinate node's wellbore inclination angle change rate, the azimuth angle change rate and the maximum drilling steering tool fluid pressure, the drilling steering tool bias force required for each wellbore trajectory coordinate node is vector-synthesized. The vector-synthesized drilling steering tool bias force includes its magnitude and direction.

[0078] Furthermore, the above step S11 can be implemented, for example, in the following manner:

[0079] According to the first well inclination, first azimuth and well depth data corresponding to each well trajectory coordinate node in the drilling well trajectory data, the well trajectory coordinate data matrix in the Cartesian coordinate system is established by applying the cylindrical spiral method and the three-dimensional data difference method.

[0080] Furthermore, the above-mentioned wellbore trajectory coordinate data matrix is ​​specifically established in the following manner:

[0081] According to the first well inclination angle, the first azimuth angle and the well depth data corresponding to each well trajectory coordinate node in the drilling well trajectory data, the cylindrical spiral method is applied to calculate and obtain the pre-processed coordinate data corresponding to each well trajectory coordinate node;

[0082] According to the pre-processed coordinate data corresponding to each wellbore trajectory coordinate node, the wellbore trajectory coordinate data after the difference corresponding to each wellbore trajectory coordinate node is calculated by applying the three-dimensional data difference method;

[0083] According to the calculated wellbore trajectory coordinate data corresponding to each wellbore trajectory coordinate node, a wellbore trajectory coordinate data matrix in a Cartesian coordinate system is established.

[0084] Furthermore, in the above step S12, the change rate of the well inclination angle of each well trajectory coordinate node is calculated by the following method:

[0085] According to the wellbore trajectory coordinate data in the wellbore trajectory coordinate data matrix, a well inclination angle calculation formula is used to calculate a second wellbore trajectory coordinate angle of each wellbore trajectory coordinate node corresponding to the wellbore trajectory coordinate data;

[0086] For example, the above-mentioned calculation formula for the well inclination angle can be:

[0087]

[0088] In the above formula, i represents the order of each wellbore trajectory coordinate node, x and z represent the x-axis coordinate and z-axis coordinate of the wellbore trajectory coordinate data corresponding to each wellbore trajectory coordinate node;

[0089] According to the second well inclination angle of each wellbore trajectory coordinate node, the well inclination angle change rate of each wellbore trajectory coordinate node is calculated using the well inclination angle change rate calculation formula;

[0090] For example, the above-mentioned calculation formula for the well inclination angle change rate can be:

[0091]

[0092] In the above formula, i represents the order of each wellbore trajectory coordinate node.

[0093] Furthermore, in the above step S12, the azimuth change rate of each wellbore trajectory coordinate node is calculated by the following method:

[0094] Calculating the second azimuth angle of each wellbore trajectory coordinate node corresponding to the wellbore trajectory coordinate data using an azimuth angle calculation formula according to the wellbore trajectory coordinate data in the wellbore trajectory coordinate data matrix;

[0095] For example, the above azimuth angle calculation formula can be:

[0096]

[0097] In the above formula, i represents the order of each wellbore trajectory coordinate node, x and y represent the x-axis coordinate and y-axis coordinate of the wellbore trajectory coordinate data corresponding to each wellbore trajectory coordinate node;

[0098] According to the second azimuth angle of each wellbore trajectory coordinate node, the azimuth angle change rate of each wellbore trajectory coordinate node is calculated using the azimuth angle change rate calculation formula;

[0099] For example, the above-mentioned azimuth angle change rate calculation formula can be:

[0100]

[0101] In the above formula, i represents the order of each wellbore trajectory coordinate node.

[0102] Furthermore, in step S13, vector synthesis of the magnitude and direction of the drilling steering tool bias force required for each wellbore trajectory coordinate node is performed based on the wellbore trajectory coordinate node's inclination angle change rate, azimuth angle change rate, and maximum drilling steering tool hydraulic pressure, which is specifically achieved by the following method:

[0103] Calculating the deflection bias force corresponding to each wellbore trajectory coordinate node using a deflection bias force calculation formula based on the well inclination angle change rate of each wellbore trajectory coordinate node and the maximum drilling steering tool fluid pressure;

[0104] The above-mentioned calculation formula for the deflection bias force may be, for example:

[0105]

[0106] In the above formula, dA devi is the rate of change of well inclination, dA max F is the maximum value of the drilling steering tool deflection angle, max is the maximum fluid pressure of the drilling steering tool;

[0107] The maximum value of the drilling steering tool's inclination angle and the maximum value of the drilling steering tool's hydraulic pressure are both derived from the actual construction parameters of the steering tool.

[0108] Calculating the azimuth bias force corresponding to each wellbore trajectory coordinate node using an azimuth bias force calculation formula based on the azimuth angle change rate of each wellbore trajectory coordinate node and the maximum drilling steering tool fluid pressure;

[0109] The above-mentioned calculation formula for the orientation bias force can be, for example:

[0110]

[0111] In the above formula, dA ori is the azimuth angle change rate, dA max F is the maximum value of the drilling steering tool deflection angle, max is the maximum fluid pressure of the drilling steering tool;

[0112] Based on the deflection bias force and azimuth bias force corresponding to each wellbore trajectory coordinate node, the magnitude of the drilling steering tool bias force required by each wellbore trajectory coordinate node is synthesized using a bias force resultant magnitude calculation formula;

[0113] The above formula for calculating the resultant bias force may be, for example:

[0114]

[0115] In the above formula, F devi is the deflection bias force, F ori To create azimuth bias force;

[0116] synthesizing the direction of the drilling steering tool bias force required for each wellbore trajectory coordinate node according to the wellbore trajectory coordinate data corresponding to each wellbore trajectory coordinate node using a bias force resultant direction calculation formula;

[0117] The above formula for calculating the direction of the resultant bias force may be, for example:

[0118]

[0119]

[0120] In the above formula, represents the drilling direction vector, represents the bias force direction vector of the drilling steering tool, and x, y, and z represent the x-axis coordinate, y-axis coordinate, and z-axis coordinate of the wellbore trajectory coordinate data corresponding to each wellbore trajectory coordinate node.

[0121] In the above-mentioned method for calculating the vector synthesis of the magnitude and direction of the drilling steering tool bias force required for each wellbore trajectory coordinate node, assuming, for example, a homogeneous formation, drilling parameters of 7 tf, a pump pressure of 15 MPa, and a torque of 11 kN·m, a PDC drill bit, and a push-type rotary steerable drilling tool, the relationship between the drilling steering tool bias force and the rate of change of the wellbore inclination angle and the rate of change of the azimuth angle follows the following formula (the coefficient needs to be adjusted according to the actual drilling conditions during actual drilling):

[0122] ΔA=2.1852e 0.1496 F

[0123] In the above formula, ΔA is the rate of change of well inclination and azimuth angle every 30m, ° / 30m; F is the bias force, kN.

[0124] Furthermore, in the above step S13, after vector synthesis of the magnitude and direction of the drilling steering tool bias force required for each wellbore trajectory coordinate node is performed, the following steps may be performed:

[0125] According to each wellbore trajectory coordinate node, in the preset three-dimensional display diagram data, the drilling steering tool bias force required for each wellbore trajectory coordinate node synthesized by vector is associated with the said each wellbore trajectory coordinate node and displayed through the said three-dimensional display diagram.

[0126] After vector synthesis of the magnitude and direction of the drilling steering tool bias force required for each wellbore trajectory coordinate node, the synthesized drilling steering tool bias force is marked on all wellbore trajectory coordinate nodes to visualize the magnitude and direction of the drilling steering tool bias force required for each wellbore trajectory coordinate node. Figure 3 As shown, Figure 3 The deviation force of the drilling steering tool at some wellbore trajectory coordinate nodes is shown. Figure 3 The line segment connected to the wellbore trajectory coordinate node is the drilling steering tool bias force corresponding to the wellbore trajectory coordinate node. The direction of the line segment represents the direction of the drilling steering tool bias force, and the length of the line segment represents the magnitude of the drilling steering tool bias force. For the convenience of visualization, Figure 3 The length of the center line segment is the length corresponding to the value after the absolute value of the drilling steering tool bias force is magnified 100 times. Figure 4 The figure shows the offset force of the drilling steering tool on the tool face at some time points. The tool face is the plane in the bending direction of the deflecting tool.

[0127] The wellbore trajectory control process is visualized, which can visualize the magnitude and direction of the offset force of the drilling guidance tool at each wellbore trajectory coordinate node during the actual drilling wellbore trajectory, providing an analysis basis for ground guidance personnel to optimize the wellbore trajectory control process. This not only makes manual error correction and improves the trajectory correction process more convenient, but also provides a technical foundation for future wellbore trajectory closed-loop control.

[0128] An embodiment of the present invention also provides a wellbore trajectory control method, which controls the trajectory of the drilling wellbore based on the vector data of the steering tool bias force obtained by the aforementioned drilling steering tool bias force mechanical behavior analysis method, thereby optimizing the wellbore trajectory control process.

[0129] The specific process of controlling the trajectory of the drilling wellbore can be referred to the existing technology and will not be described in detail here.

[0130] Based on the same inventive concept, an embodiment of the present invention also provides a drilling guide tool bias force mechanical behavior analysis device. Since the principle of the problem solved by the device is similar to the aforementioned drilling guide tool bias force mechanical behavior analysis method, the implementation of the device can refer to the implementation of the aforementioned method, and the repeated parts will not be repeated.

[0131] The embodiment of the present invention provides a drilling steering tool bias force mechanical behavior analysis device, referring to Figure 5 As shown, including:

[0132] Establishing module 51, for establishing a wellbore trajectory coordinate data matrix based on the drilling wellbore trajectory data;

[0133] A calculation module 52 is configured to calculate, based on the wellbore trajectory coordinate data in the wellbore trajectory coordinate data matrix, a well inclination angle change rate and an azimuth angle change rate of each wellbore trajectory coordinate node corresponding to the wellbore trajectory coordinate data;

[0134] The synthesis module 53 is used to perform vector synthesis on the magnitude and direction of the drilling steering tool bias force required for each wellbore trajectory coordinate node according to the well inclination angle change rate, azimuth angle change rate and maximum drilling steering tool fluid pressure of each wellbore trajectory coordinate node.

[0135] An embodiment of the present invention provides a computer-readable storage medium storing a computer program. When the computer program is executed by a processor, the computer program implements the aforementioned method for analyzing the mechanical behavior of the bias force of a drilling guide tool.

[0136] An embodiment of the present invention provides a computer program product, which includes a computer program. When the computer program is executed by a processor, it implements the above-mentioned method for analyzing the mechanical behavior of the offset force of the drilling steering tool.

[0137] Regarding the apparatus in the above embodiment, the specific manner in which each module performs operations has been described in detail in the embodiment of the method, and will not be elaborated here.

[0138] It should be understood that the specific order or hierarchy of steps in the disclosed processes is an example of an exemplary method. Based on design preferences, it should be understood that the specific order or hierarchy of steps in the process can be rearranged without departing from the scope of the present disclosure. The accompanying method claims present elements of the various steps in an exemplary order and are not intended to be limited to the specific order or hierarchy described.

[0139] Those skilled in the art will appreciate that embodiments of the present invention may be provided as methods, systems, or computer program products. Thus, the present invention may take the form of an entirely hardware embodiment, an entirely software embodiment, or an embodiment combining software and hardware. Furthermore, the present invention may take the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to magnetic disk storage and optical storage, etc.) containing computer-usable program code.

[0140] The present invention is described with reference to flowcharts and / or block diagrams of methods, devices (systems), and computer program products according to embodiments of the present invention. It should be understood that each process and / or block in the flowcharts and / or block diagrams, as well as combinations of processes and / or blocks in the flowcharts 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, a special-purpose computer, an embedded processor, or other programmable data processing device to produce a machine, so that the instructions executed by the processor of the computer or other programmable data processing device generate instructions for implementing the processes in the flowcharts and / or block diagrams. Figure 1 a process or multiple processes and / or boxes Figure 1 A device that provides the functions specified in a block or multiple blocks.

[0141] These computer program instructions may also be stored in a computer readable memory that can direct a computer or other programmable data processing device to work in a specific manner, so that the instructions stored in the computer readable memory produce an article of manufacture comprising an instruction device, which implements the process Figure 1 a process or multiple processes and / or boxes Figure 1 The function specified in one or more boxes.

[0142] These computer program instructions can also be loaded onto a computer or other programmable data processing device so that a series of operational steps are executed on the computer or other programmable device to produce a computer-implemented process, thereby providing the instructions executed on the computer or other programmable device for implementing the process. Figure 1a process or multiple processes and / or boxes Figure 1 A step that specifies a function in one or more boxes.

[0143] Obviously, those skilled in the art may make various changes and modifications to the present invention without departing from the spirit and scope of the present invention. Thus, if such changes and modifications fall within the scope of the claims and their equivalents, the present invention is intended to include such changes and modifications.

Claims

1. A method for analyzing the mechanical behavior of the bias force of a drilling steering tool, characterized in that: include: Establishing a wellbore trajectory coordinate data matrix based on drilling wellbore trajectory data; Calculating the inclination angle change rate and the azimuth angle change rate of each wellbore trajectory coordinate node corresponding to the wellbore trajectory coordinate data according to the wellbore trajectory coordinate data in the wellbore trajectory coordinate data matrix; Performing vector synthesis of the magnitude and direction of the drilling steering tool bias force required for each wellbore trajectory coordinate node based on the well inclination angle change rate, the azimuth angle change rate, and the maximum drilling steering tool fluid pressure at each wellbore trajectory coordinate node; The step of establishing a wellbore trajectory coordinate data matrix based on the drilling wellbore trajectory data includes: According to the first well inclination angle, first azimuth angle and well depth data corresponding to each well trajectory coordinate node in the drilling well trajectory data, a well trajectory coordinate data matrix in a Cartesian coordinate system is established by applying the cylindrical spiral method and the three-dimensional data difference method; The method of establishing a wellbore trajectory coordinate data matrix in a Cartesian coordinate system by applying a cylindrical spiral method and a three-dimensional data difference method according to the first well inclination angle, the first azimuth angle, and the well depth data corresponding to each wellbore trajectory coordinate node in the drilling wellbore trajectory data includes: According to the first well inclination angle, the first azimuth angle and the well depth data corresponding to each well trajectory coordinate node in the drilling well trajectory data, the cylindrical spiral method is applied to calculate and obtain the pre-processed coordinate data corresponding to each well trajectory coordinate node; According to the pre-processed coordinate data corresponding to each wellbore trajectory coordinate node, the wellbore trajectory coordinate data corresponding to each wellbore trajectory coordinate node is calculated by applying a three-dimensional data difference method; Establishing a wellbore trajectory coordinate data matrix in a Cartesian coordinate system based on the wellbore trajectory coordinate data corresponding to each wellbore trajectory coordinate node obtained by the calculation; Calculating the wellbore trajectory coordinate data in the wellbore trajectory coordinate data matrix according to the wellbore trajectory coordinate data, and calculating the well inclination angle change rate of each wellbore trajectory coordinate node corresponding to the wellbore trajectory coordinate data, including: Calculating a second well inclination angle of each well trajectory coordinate node corresponding to the well trajectory coordinate data using a well inclination angle calculation formula according to the well trajectory coordinate data in the well trajectory coordinate data matrix; According to the second well inclination angle of each wellbore trajectory coordinate node, the well inclination angle change rate of each wellbore trajectory coordinate node is calculated using the well inclination angle change rate calculation formula; Calculating the azimuth change rate of each wellbore trajectory coordinate node corresponding to the wellbore trajectory coordinate data according to the wellbore trajectory coordinate data in the wellbore trajectory coordinate data matrix includes: Calculating the second azimuth angle of each wellbore trajectory coordinate node corresponding to the wellbore trajectory coordinate data using an azimuth angle calculation formula according to the wellbore trajectory coordinate data in the wellbore trajectory coordinate data matrix; According to the second azimuth of each wellbore trajectory coordinate node, the azimuth change rate of each wellbore trajectory coordinate node is calculated using the azimuth change rate calculation formula.

2. The method according to claim 1, wherein The calculation formula for the well inclination angle is: In the above formula, i represents the order of each wellbore trajectory coordinate node, x and z represent the x-axis coordinate and z-axis coordinate of the wellbore trajectory coordinate data corresponding to each wellbore trajectory coordinate node; The calculation formula for the well inclination angle change rate is: In the above formula, i represents the order of each wellbore trajectory coordinate node.

3. The method according to claim 1, wherein The azimuth angle calculation formula is: In the above formula, i represents the order of each wellbore trajectory coordinate node, x and y represent the x-axis coordinate and y-axis coordinate of the wellbore trajectory coordinate data corresponding to each wellbore trajectory coordinate node; The azimuth angle change rate calculation formula is: In the above formula, i represents the order of each wellbore trajectory coordinate node.

4. The method according to claim 1, wherein Performing vector synthesis of the magnitude and direction of the drilling steering tool bias force required for each wellbore trajectory coordinate node based on the wellbore trajectory change rate, the azimuth change rate, and the maximum drilling steering tool fluid pressure of each wellbore trajectory coordinate node, including: Calculating the deflection bias force corresponding to each wellbore trajectory coordinate node using a deflection bias force calculation formula based on the well inclination angle change rate of each wellbore trajectory coordinate node and the maximum drilling steering tool fluid pressure; Calculating the azimuth bias force corresponding to each wellbore trajectory coordinate node using an azimuth bias force calculation formula based on the azimuth angle change rate of each wellbore trajectory coordinate node and the maximum drilling steering tool fluid pressure; Based on the deflection bias force and azimuth bias force corresponding to each wellbore trajectory coordinate node, the magnitude of the drilling steering tool bias force required by each wellbore trajectory coordinate node is synthesized using a bias force resultant magnitude calculation formula; The directions of the drilling steering tool bias forces required for the respective wellbore trajectory coordinate nodes are synthesized using a bias force resultant direction calculation formula based on the wellbore trajectory coordinate data corresponding to the respective wellbore trajectory coordinate nodes.

5. The method according to claim 4, wherein The calculation formula for the deflection bias force is: In the above formula, dA devi is the rate of change of well inclination, dA max F is the maximum value of the drilling steering tool deflection angle, max is the maximum fluid pressure of the drilling steering tool; The calculation formula for the orientation bias force is: In the above formula, dA ori is the azimuth angle change rate, dA max F is the maximum value of the drilling steering tool deflection angle, max is the maximum fluid pressure of the drilling steering tool; The calculation formula for the resultant bias force is: In the above formula, F devi is the deflection bias force, F ori To create azimuth bias force; The calculation formula for the direction of the resultant bias force is: In the above formula, represents the drilling direction vector, represents the bias force direction vector of the drilling steering tool, and x, y, and z represent the x-axis coordinate, y-axis coordinate, and z-axis coordinate of the wellbore trajectory coordinate data corresponding to each wellbore trajectory coordinate node.

6. The method according to claim 1, wherein After vector synthesis of the magnitude and direction of the drilling steering tool bias force required for each wellbore trajectory coordinate node based on the well inclination angle change rate, the azimuth angle change rate, and the maximum drilling steering tool hydraulic pressure at each wellbore trajectory coordinate node, the method further includes: According to each wellbore trajectory coordinate node, in the preset three-dimensional display diagram data, the drilling steering tool bias force required for each wellbore trajectory coordinate node synthesized by vector is associated with the said each wellbore trajectory coordinate node and displayed through the said three-dimensional display diagram.

7. A wellbore trajectory control method, characterized in that: The trajectory of the drilling wellbore is controlled according to the vector data of the steering tool bias force obtained by the drilling steering tool bias force mechanical behavior analysis method according to any one of claims 1 to 6.

8. A computer-readable storage medium, characterized in that The computer-readable storage medium stores a computer program, and when the computer program is executed by a processor, the method for analyzing the mechanical behavior of the bias force of a drilling steering tool according to any one of claims 1 to 6 is implemented.

9. A computer program product, characterized in that The computer program product comprises a computer program, and when the computer program is executed by a processor, the method for analyzing the mechanical behavior of the bias force of a drilling steering tool according to any one of claims 1 to 6 is implemented.

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