Drill bit optimization method and apparatus based on data analysis

Abstract

The application provides a drilling bit optimization method and device based on data analysis, and relates to the technical field of well drilling analysis. The method comprises the following steps: obtaining the use parameters of a drilling bit in a target stratum; calculating the average rate of penetration and the average footage of each drilling bit according to the rate of penetration and the footage in the use parameters; taking the average rate of penetration and the average footage as the horizontal coordinate and the vertical coordinate of a Cartesian coordinate system respectively, and marking the average rate of penetration and the average footage of each drilling bit in the coordinate system; selecting different reference indexes according to the well depth data of the target stratum, and partitioning the coordinate system; and selecting the drilling bit model in the coordinate system as the optimized drilling bit model according to the partitioning condition. The application has sufficient theoretical basis, is simple and easy to use, can greatly improve the scientificity and rationality of drilling bit selection in the drilling industry, has high drilling bit selection accuracy, can greatly improve the drilling efficiency, and reduces the drilling investment cost.

Description

Technical Field

[0001] This invention relates to the field of drilling analysis technology, and more particularly to a method and apparatus for drill bit optimization based on data analysis. Background Technology

[0002] This section is intended to provide background or context for the embodiments of the invention set forth in the claims. The description herein is not an admission that it is prior art simply because it is included in this section.

[0003] During drilling, the drill bit is the primary tool for breaking rocks, and the wellbore is formed by the drill bit breaking rocks. The quality of wellbore formation and the time taken to form depend not only on the characteristics of the rock formation being drilled and the performance of the drill bit itself, but also, and perhaps more importantly, on the degree of compatibility between the drill bit and the formation. Appropriate drill bit selection plays a crucial role in improving drilling speed and reducing overall drilling costs.

[0004] Currently, existing drill bit selection methods mainly include: 1. Simulating a virtual strength by analyzing various parameters during the drilling process and then comparing it with the expected value to determine the drill bit's compatibility with the formation, thus achieving the purpose of drill bit selection. 2. Evaluating rock drillability by analyzing the element content in rock cuttings, and then selecting a suitable drill bit for drilling the current formation based on experience, thus achieving the purpose of drill bit selection. 3. Layering the formation using rock mechanics parameters, determining the various parameters of the required drill bit based on the drilling purpose and requirements, and then comparing them with the structural parameters of adjacent wells and stored drill bits to select the required drill bit, thus achieving the purpose of selection. 4. Analyzing the drill bit's usage parameters, performing evaluation calculations to obtain a multi-parameter evaluation index value matrix and a single-parameter evaluation index value matrix, and using the evaluation index value matrix to select the drill bit.

[0005] However, the selection results obtained through the above-mentioned drill bit selection methods have the following drawbacks: poor formation specificity, weak data support, and insufficient application reliability. Moreover, most selection methods are theoretical and lack sufficient guidance for actual drilling operations. Therefore, the selected drill bits are not the most reasonable and the accuracy of drill bit selection is low.

[0006] In summary, there is an urgent need for a technical solution that can overcome the above-mentioned shortcomings, select the most appropriate drill bit, and improve the accuracy of the selection. Summary of the Invention

[0007] To address the problems existing in the prior art, this invention proposes a data analysis-based method and apparatus for drill bit optimization.

[0008] In a first aspect of the present invention, a drill bit selection method based on data analysis is proposed, comprising:

[0009] Obtain the operating parameters of the drill bit in the target formation;

[0010] Based on the mechanical drilling rate and footage in the aforementioned usage parameters, the average mechanical drilling rate and average footage for each type of drill bit are calculated respectively.

[0011] Using the average mechanical drilling rate and average footage as the abscissa and ordinate of the Cartesian coordinate system, respectively, the average mechanical drilling rate and average footage of each type of drill bit are marked in the coordinate system.

[0012] Based on the well depth data of the target formation, different reference indicators are selected to partition the coordinate system.

[0013] Based on the zoning situation, the preferred drill bit model is selected in the coordinate system.

[0014] In a second aspect of the present invention, a drill bit selection device based on data analysis is provided, comprising:

[0015] The parameter acquisition module is used to acquire the operating parameters of the drill bit in the target formation.

[0016] The calculation module is used to calculate the average mechanical drilling speed and average footage for each type of drill bit based on the mechanical drilling speed and footage in the usage parameters.

[0017] The marking module is used to mark the average mechanical drilling rate and average footage of each drill bit in the Cartesian coordinate system, with the average mechanical drilling rate and average footage as the abscissa and ordinate respectively.

[0018] The partitioning module is used to partition the coordinate system by selecting different reference indicators based on the well depth data of the target formation;

[0019] The drill bit selection module is used to select the preferred drill bit model in the coordinate system according to the zoning situation.

[0020] In a third aspect of the present invention, a computer device is provided, including a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the computer program to implement a drill bit optimization method based on data analysis.

[0021] In a fourth aspect of the present invention, a computer-readable storage medium is provided, the computer-readable storage medium storing a computer program that, when executed by a processor, implements a drill bit optimization method based on data analysis.

[0022] In a fifth aspect of the present invention, a computer program product is provided, the computer program product comprising a computer program that, when executed by a processor, implements a drill bit optimization method based on data analysis.

[0023] The present invention proposes a data analysis-based drill bit selection method and apparatus. This method obtains the usage parameters of drill bits in the target formation; calculates the average mechanical drilling rate and average footage for each type of drill bit based on the mechanical drilling rate and footage in the usage parameters; marks the average mechanical drilling rate and average footage of each drill bit in the Cartesian coordinate system, using the average mechanical drilling rate and average footage as the x and y coordinates, respectively; partitions the coordinate system according to the well depth data of the target formation and different reference indicators; selects the preferred drill bit model in the coordinate system based on the partitioning; the overall scheme statistically analyzes the average mechanical drilling rate and average footage data based on drill bit usage, extracts indicator data reflecting the effectiveness of drill bit selection, evaluates the drill bit model using a data polygon partitioning analysis method, extracts comprehensive indicators of drill bit models for different well depths, and thus selects the preferred drill bit model. This invention has a sound theoretical basis, is simple and easy to operate, and can significantly improve the scientific and rational nature of drill bit selection in the drilling industry. It boasts high drill bit selection accuracy, and large-scale application can significantly improve drilling efficiency and reduce drilling investment costs. Attached Figure Description

[0024] To more clearly illustrate the technical solutions of the embodiments of this application, the drawings used in the description of the embodiments will be briefly introduced below. Obviously, the drawings described below are some embodiments of this application. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0025] Figure 1 This is a schematic flowchart of a data analysis-based drill bit selection method according to an embodiment of the present invention.

[0026] Figure 2 This is a schematic diagram of the coordinate system partitioning of a shallow well section according to a specific embodiment of the present invention.

[0027] Figure 3 This is a schematic diagram of the coordinate system partitioning of medium-deep and deep well sections according to a specific embodiment of the present invention.

[0028] Figure 4 This is a schematic diagram of the architecture of a drill bit optimization device based on data analysis according to an embodiment of the present invention.

[0029] Figure 5 This is a schematic diagram of a computer device structure according to an embodiment of the present invention. Detailed Implementation

[0030] The principles and spirit of the invention will now be described with reference to several exemplary embodiments. It should be understood that these embodiments are given merely to enable those skilled in the art to better understand and implement the invention, and are not intended to limit the scope of the invention in any way. Rather, these embodiments are provided to make this disclosure more thorough and complete, and to fully convey the scope of this disclosure to those skilled in the art.

[0031] Those skilled in the art will recognize that embodiments of the present invention can be implemented as a system, apparatus, device, method, or computer program product. Therefore, this disclosure can be specifically implemented in the following forms: entirely hardware, entirely software (including firmware, resident software, microcode, etc.), or a combination of hardware and software.

[0032] According to an embodiment of the present invention, a method and apparatus for drill bit optimization based on data analysis are proposed, relating to the field of drilling analysis technology.

[0033] The principles and spirit of the present invention will be explained in detail below with reference to several representative embodiments.

[0034] Figure 1 This is a schematic flowchart of a data analysis-based drill bit optimization method according to an embodiment of the present invention. Figure 1 As shown, the method includes:

[0035] S1, obtain the usage parameters of the drill bit in the target formation;

[0036] S2, based on the mechanical drilling speed and footage in the usage parameters, calculate the average mechanical drilling speed and average footage for each type of drill bit;

[0037] S3, using the average mechanical drilling speed and average footage as the abscissa and ordinate of the Cartesian coordinate system respectively, the average mechanical drilling speed and average footage of each drill bit are marked in the coordinate system;

[0038] S4. Based on the well depth data of the target formation, select different reference indicators to partition the coordinate system;

[0039] S5. Select the preferred drill bit model in the coordinate system according to the partitioning situation.

[0040] This invention is based on sound theory, is simple and easy to operate, and can significantly improve the scientific and rational selection of drill bits in the drilling industry. It has a high accuracy rate in drill bit selection, and large-scale promotion can greatly improve drilling efficiency and reduce drilling investment costs.

[0041] To provide a clearer explanation of the above-mentioned data analysis-based drill bit optimization method, a detailed description is provided below with reference to specific embodiments.

[0042] In S1, obtain the usage parameters of the drill bit in the target formation.

[0043] In one specific embodiment, the parameters for using the drill bit in the target formation also include: drilling pressure, displacement, pump pressure, and drilling fluid density;

[0044] After the drill bit selection is completed, the usage parameters of the selected drill bit model will be presented in tabular form.

[0045] In S2, the average mechanical drilling speed and average footage for each type of drill bit are calculated based on the mechanical drilling speed and footage in the usage parameters.

[0046] The formulas for calculating the average mechanical drilling speed and average footage for each type of drill bit are as follows:

[0047]

[0048] Among them, V i Let be the average mechanical drilling speed of the i-th type of drill bit;

[0049] L i Let be the average depth of the i-th type of drill bit;

[0050] m represents the number of times this type of drill bit is used in a specified formation;

[0051] V j This is the mechanical drilling speed of this type of drill bit during its jth use.

[0052] L j This refers to the single advance of this type of drill bit during its jth use.

[0053] In S3, the average mechanical drilling speed and average footage are used as the abscissa and ordinate of the Cartesian coordinate system, respectively, and the average mechanical drilling speed and average footage of each type of drill bit are marked in the coordinate system.

[0054] In S4, different reference indices are selected based on the well depth data of the target formation to partition the coordinate system.

[0055] Based on the average mechanical drilling speed and average footage of each type of drill bit, calculate the average mechanical drilling speed and average footage of the drill bit for the target formation. The calculation formula is as follows:

[0056]

[0057] Among them, V P The average mechanical drilling speed of the drill bit in the target formation;

[0058] L P The average footage of the target formation;

[0059] n represents the number of drill bit types for the target formation;

[0060] V i Let be the average mechanical drilling speed of the i-th type of drill bit;

[0061] L i Let be the average depth of the i-th type of drill bit;

[0062] The coordinate system is divided into partitions using the average mechanical drilling rate and average footage of the target formation drill bit as reference indicators.

[0063] refer to Figure 2 This is a schematic diagram of the coordinate system partitioning of a shallow well section according to a specific embodiment of the present invention. Figure 2 As shown, the average mechanical drilling rate is used as the main analysis index for shallow well sections. Based on the average mechanical drilling rate, the coordinate point with the most footage, and the coordinate point with the fastest drilling rate, the coordinate system is divided into 4 regions.

[0064] When dividing the shallow well section into zones, draw a rectangle in the coordinate system based on the coordinate points with the maximum footage and the fastest drilling speed. These two coordinate points are located at the upper left and lower right corners of the rectangle, respectively. Draw a first dividing line (this line passes through the coordinate points with the maximum footage and the fastest drilling speed).

[0065] The triangle formed by the first dividing line, the left side of the rectangle, and the bottom edge of the rectangle is area I.

[0066] Based on the average mechanical drilling rate, draw a second dividing line perpendicular to the drilling rate coordinate axis. The second dividing line intersects the top edge of the rectangle and the first dividing line. Draw a third dividing line parallel to the drilling rate coordinate axis and intersects the second dividing line and the first dividing line at the intersection.

[0067] The triangle formed by the second dividing line, the first dividing line, and the top edge of the rectangle is area II;

[0068] The triangle formed by the third dividing line, the first dividing line, and the right side of the rectangle is zone II.

[0069] Draw the fourth dividing line, which intersects the second dividing line at the intersection of the top edge of the rectangle and the third dividing line at the intersection of the right edge of the rectangle.

[0070] The triangle formed by the second, third, and fourth dividing lines is zone III.

[0071] The triangle formed by the fourth dividing line, the top edge of the rectangle, and the right edge of the rectangle is zone IV.

[0072] Among them, Figure 2In the coordinate system, from bottom left to top right, the zones are: Zone I, Zone II (composed of two parts), Zone III, and Zone IV. The priority is: Zone IV > Zone III > Zone II > Zone I. When both are in Zone II, faster drilling speed is the second preferred indicator.

[0073] refer to Figure 3 This is a schematic diagram of the coordinate system partitioning for medium-deep and deep well sections according to a specific embodiment of the present invention. Figure 3 As shown, for medium and deep well sections, the average footage is used as the main analysis index. Based on the average mechanical drilling speed, the coordinate point with the most footage, and the coordinate point with the fastest drilling speed, the coordinate system is divided into 4 regions.

[0074] When dividing the medium-deep and deep well sections, draw a rectangle in the coordinate system based on the coordinate points with the maximum footage and the fastest drilling speed. These two coordinate points are located at the upper left and lower right corners of the rectangle, respectively. Draw a first dividing line (this line passes through the coordinate points with the maximum footage and the fastest drilling speed).

[0075] The triangle formed by the first dividing line, the left side of the rectangle, and the bottom edge of the rectangle is area I.

[0076] Based on the average drilling footage, draw a second dividing line parallel to the drilling speed coordinate axis. The second dividing line intersects with the first dividing line and the right side of the rectangle. Draw a third dividing line, which is perpendicular to the drilling speed coordinate axis and intersects with the intersection of the second dividing line and the first dividing line.

[0077] The triangle formed by the third dividing line, the first dividing line, and the top edge of the rectangle is area II;

[0078] The triangle formed by the second dividing line, the first dividing line, and the right side of the rectangle is area II.

[0079] Draw the fourth dividing line, which intersects the third dividing line at the point where it intersects the top edge of the rectangle, and the second dividing line at the point where it intersects the right edge of the rectangle.

[0080] The triangle formed by the second, third, and fourth dividing lines is zone III.

[0081] The triangle formed by the fourth dividing line, the top edge of the rectangle, and the right edge of the rectangle is zone IV.

[0082] In the coordinate system, from bottom left to top right, the zones are: Zone I, Zone II (composed of two parts), Zone III, and Zone IV, with the priority being: Zone IV > Zone III > Zone II > Zone I. When both are in Zone II, the longer advance length is taken as the second preferred indicator.

[0083] In S5, the preferred drill bit model is selected in the coordinate system according to the partitioning situation.

[0084] Compared with the prior art, the present invention has at least the following advantages:

[0085] 1. This invention acquires and statistically analyzes the operating parameters of various drill bits used in a specified formation. Then, using the drilling speed and footage of all drill bits as two core evaluation indicators, it takes the arithmetic average reflecting the concentration trend of various drill bits. For shallow well sections, the average mechanical drilling speed is used as the primary analysis indicator, and the drilling speed and footage coordinate system is used for regional division. For medium- and deep well sections, the average footage is used as the primary analysis indicator, and the drilling speed and footage coordinate system is used for regional division. Finally, the optimal results are visually represented through a coordinate system, effectively improving the accuracy of drill bit selection. Furthermore, it is highly implementable and practical in real-world applications, easy to operate and promote, and can effectively improve the efficiency of drill bit selection, with broad application prospects.

[0086] 2. The preferred results of this invention are supported by a large number of actual drill bit usage parameters. Compared with other theoretical selection methods, the selection results of this invention are more targeted and more reliable.

[0087] 3. The selection results of the drill bit in this invention are visualized through scatter points and data analysis polygons in a coordinate system, which is intuitive and simple. Furthermore, the important parameters of the drill bit during the drilling process are given in tabular form, which makes the guidance more intuitive.

[0088] It should be noted that although the operation of the method of the present invention has been described in a specific order in the above embodiments and figures, this does not require or imply that the operations must be performed in that specific order, or that all the operations shown must be performed to achieve the desired result. Additionally or alternatively, certain steps may be omitted, multiple steps may be combined into one step, and / or one step may be broken down into multiple steps.

[0089] After introducing the method of exemplary embodiments of the present invention, the following references are made. Figure 4 A data analysis-based drill bit selection device according to an exemplary embodiment of the present invention will be described.

[0090] The implementation of the data analysis-based drill bit optimization device can refer to the implementation of the above method, and the repeated parts will not be described again. The term "module" or "unit" used below can be a combination of software and / or hardware to achieve a predetermined function. Although the device described in the following embodiments is preferably implemented in software, hardware implementation, or a combination of software and hardware, is also possible and contemplated.

[0091] Based on the same inventive concept, this invention also proposes a drill bit optimization device based on data analysis, such as... Figure 4 As shown, the device includes:

[0092] The parameter acquisition module 410 is used to acquire the operating parameters of the drill bit in the target formation.

[0093] The calculation module 420 is used to calculate the average mechanical drilling speed and average footage for each type of drill bit based on the mechanical drilling speed and footage in the usage parameters.

[0094] The marking module 430 is used to mark the average mechanical drilling speed and average footage of each drill bit in the Cartesian coordinate system, with the average mechanical drilling speed and average footage as the abscissa and ordinate respectively.

[0095] The partitioning module 440 is used to partition the coordinate system by selecting different reference indicators based on the well depth data of the target formation;

[0096] The drill bit selection module 450 is used to select the preferred drill bit model in the coordinate system according to the partitioning situation.

[0097] It should be noted that although several modules of the data analysis-based drill bit optimization device have been mentioned in the detailed description above, this division is merely exemplary and not mandatory. In fact, according to embodiments of the present invention, the features and functions of two or more modules described above can be embodied in one module. Conversely, the features and functions of one module described above can be further divided and embodied by multiple modules.

[0098] Based on the aforementioned inventive concept, such as Figure 5 As shown, the present invention also proposes a computer device 500, including a memory 510, a processor 520, and a computer program 530 stored in the memory 510 and executable on the processor 520. When the processor 520 executes the computer program 530, it implements the aforementioned drill bit optimization method based on data analysis.

[0099] Based on the aforementioned inventive concept, the present invention proposes a computer-readable storage medium storing a computer program, which, when executed by a processor, implements the aforementioned data analysis-based drill bit optimization method.

[0100] Based on the aforementioned inventive concept, the present invention proposes a computer program product, which includes a computer program that, when executed by a processor, implements a drill bit optimization method based on data analysis.

[0101] The present invention proposes a data analysis-based drill bit selection method and apparatus. This method obtains the usage parameters of drill bits in the target formation; calculates the average mechanical drilling rate and average footage for each type of drill bit based on the mechanical drilling rate and footage in the usage parameters; marks the average mechanical drilling rate and average footage of each drill bit in the Cartesian coordinate system, using the average mechanical drilling rate and average footage as the x and y coordinates, respectively; partitions the coordinate system according to the well depth data of the target formation and different reference indicators; selects the preferred drill bit model in the coordinate system based on the partitioning; the overall scheme statistically analyzes the average mechanical drilling rate and average footage data based on drill bit usage, extracts indicator data reflecting the effectiveness of drill bit selection, evaluates the drill bit model using a data polygon partitioning analysis method, extracts comprehensive indicators of drill bit models for different well depths, and thus selects the preferred drill bit model. This invention has a sound theoretical basis, is simple and easy to operate, and can significantly improve the scientific and rational nature of drill bit selection in the drilling industry. It boasts high drill bit selection accuracy, and large-scale application can significantly improve drilling efficiency and reduce drilling investment costs.

[0102] The acquisition, storage, use, and processing of data in this application all comply with the relevant provisions of national laws and regulations.

[0103] Those skilled in the art will understand that embodiments of the present invention can be provided as methods, apparatus, or computer program products. Therefore, the present invention can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, the present invention 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.

[0104] This invention is described with reference to flowchart illustrations and / or block diagrams of methods and computer program products according to embodiments of the invention. 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 flowchart illustrations and / or block diagrams. Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0105] 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.

[0106] 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.

[0107] Finally, it should be noted that the above-described embodiments are merely specific implementations of the present invention, used to illustrate the technical solutions of the present invention, and not to limit it. The scope of protection of the present invention is not limited thereto. Although the present invention has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that any person skilled in the art can still modify or easily conceive of changes to the technical solutions described in the foregoing embodiments within the technical scope disclosed in the present invention, or make equivalent substitutions for some of the technical features; and these modifications, changes, or substitutions do not cause the essence of the corresponding technical solutions to deviate from the spirit and scope of the technical solutions of the embodiments of the present invention, and should all be covered within the scope of protection of the present invention. Therefore, the scope of protection of the present invention should be determined by the scope of the claims.

Claims

1. A drill bit optimization method based on data analysis, characterized in that, include: Obtain the operating parameters of the drill bit in the target formation; Based on the mechanical drilling rate and footage in the aforementioned usage parameters, the average mechanical drilling rate and average footage for each type of drill bit are calculated respectively. Using the average mechanical drilling rate and average footage as the abscissa and ordinate of the Cartesian coordinate system, respectively, the average mechanical drilling rate and average footage of each type of drill bit are marked in the coordinate system. Based on the well depth data of the target formation, different reference indicators are selected to partition the coordinate system. Based on the zoning situation, the preferred drill bit model is selected in the coordinate system. Specifically, based on the well depth data of the target formation, different reference indices are selected to partition the coordinate system, including: Calculate the average mechanical drilling rate and average footage of the drill bit for the target formation based on the average mechanical drilling rate and average footage of each drill bit. The coordinate system is divided into partitions using the average mechanical drilling speed and average footage of the target formation drill bit as reference indicators. For shallow well sections, the average mechanical drilling speed of the target formation drill bit is used as the main analysis index. Based on the average mechanical drilling speed of the target formation drill bit, the coordinate point with the most footage, and the coordinate point with the fastest drilling speed, the coordinate system is divided into 4 regions. When dividing the shallow well section into zones, draw a rectangle in the coordinate system based on the coordinate points with the maximum footage and the fastest drilling speed. These two coordinate points are located at the upper left and lower right corners of the rectangle, respectively. Draw a first dividing line that passes through the coordinate points with the maximum footage and the fastest drilling speed. The triangle formed by the first dividing line, the left side of the rectangle, and the bottom edge of the rectangle is area I; Based on the average mechanical drilling rate, draw a second dividing line perpendicular to the drilling rate coordinate axis. The second dividing line intersects the top edge of the rectangle and the first dividing line. Draw a third dividing line parallel to the drilling rate coordinate axis and intersects the second dividing line and the first dividing line at the intersection. The triangle formed by the second dividing line, the first dividing line, and the top edge of the rectangle is area II; The triangle formed by the third dividing line, the first dividing line, and the right side of the rectangle is area II; Draw the fourth dividing line, which intersects the second dividing line at the intersection of the top edge of the rectangle and the third dividing line at the intersection of the right edge of the rectangle. The triangle formed by the second, third, and fourth dividing lines is zone III; The triangle formed by the fourth dividing line, the top edge of the rectangle, and the right edge of the rectangle is zone IV. In the coordinate system, from the lower left to the upper right, they are: Zone I, Zone II, Zone III, and Zone IV. Zone II consists of two parts, with the priority being: Zone IV > Zone III > Zone II > Zone I. When both are in Zone II, faster drilling speed is the second preferred indicator. For medium-deep and deep well sections, the average footage of the drill bit in the target formation is used as the main analysis index. Based on the average footage of the drill bit in the target formation, the coordinate point with the most footage, and the coordinate point with the fastest drilling speed, the coordinate system is divided into 4 regions. When dividing the medium-deep and deep well sections, draw a rectangle in the coordinate system based on the coordinate points with the maximum footage and the fastest drilling speed. These two coordinate points are located at the upper left and lower right corners of the rectangle, respectively. Draw a first dividing line that passes through the coordinate points with the maximum footage and the fastest drilling speed. The triangle formed by the first dividing line, the left side of the rectangle, and the bottom edge of the rectangle is area I; Based on the average drilling footage, draw a second dividing line parallel to the drilling speed coordinate axis. The second dividing line intersects with the first dividing line and the right side of the rectangle. Draw a third dividing line, which is perpendicular to the drilling speed coordinate axis and intersects with the intersection of the second dividing line and the first dividing line. The triangle formed by the third dividing line, the first dividing line, and the top edge of the rectangle is area II; The triangle formed by the second dividing line, the first dividing line, and the right side of the rectangle is area II; Draw the fourth dividing line, which intersects the third dividing line at the point where it intersects the top edge of the rectangle, and the second dividing line at the point where it intersects the right edge of the rectangle. The triangle formed by the second, third, and fourth dividing lines is zone III; The triangle formed by the fourth dividing line, the top edge of the rectangle, and the right edge of the rectangle is zone IV. In the coordinate system, from bottom left to top right, the zones are: Zone I, Zone II, Zone III, and Zone IV. Zone II consists of two parts, with the priority being: Zone IV > Zone III > Zone II > Zone I. When both are in Zone II, the longer advance length is taken as the second preferred indicator.

2. The method according to claim 1, characterized in that, Based on the mechanical drilling rate and footage in the aforementioned usage parameters, the average mechanical drilling rate and average footage for each type of drill bit are calculated, including: The formulas for calculating the average mechanical drilling speed and average footage for each type of drill bit are as follows: ； ； in, For the first i The average mechanical drilling speed of the drill bit; For the first i Average depth of the drill bit; m This refers to the number of times this type of drill bit can be used in a specified formation; For this type of drill bit, in the... j Mechanical drilling speed during first use; L j For this type of drill bit, in the... j Single advance during the first use.

3. The method according to claim 1, characterized in that, The formulas for calculating the average mechanical drilling rate and average footage of the drill bit in the target formation are as follows: ； ； in, The average mechanical drilling speed of the drill bit in the target formation; The average footage of the target formation; n The number of drill bit types for the target formation; For the first i The average mechanical drilling speed of the drill bit; For the first i The average depth of the drill bit.

4. The method according to claim 1, characterized in that, The parameters for using the drill bit in the target formation also include: drilling pressure, displacement, pump pressure, and drilling fluid density; After the drill bit selection is completed, the usage parameters of the selected drill bit model will be presented in tabular form.

5. A drill bit selection device based on data analysis, characterized in that, include: The parameter acquisition module is used to acquire the operating parameters of the drill bit in the target formation. The calculation module is used to calculate the average mechanical drilling speed and average footage for each type of drill bit based on the mechanical drilling speed and footage in the usage parameters. The marking module is used to mark the average mechanical drilling rate and average footage of each drill bit in the Cartesian coordinate system, with the average mechanical drilling rate and average footage as the abscissa and ordinate respectively. The partitioning module is used to partition the coordinate system by selecting different reference indicators based on the well depth data of the target formation; The drill bit selection module is used to select the preferred drill bit model in the coordinate system according to the zoning situation. Specifically, the partitioning module is used for: Calculate the average mechanical drilling rate and average footage of the drill bit for the target formation based on the average mechanical drilling rate and average footage of each drill bit. The coordinate system is divided into partitions using the average mechanical drilling speed and average footage of the target formation drill bit as reference indicators. For shallow well sections, the average mechanical drilling speed of the target formation drill bit is used as the main analysis index. Based on the average mechanical drilling speed of the target formation drill bit, the coordinate point with the most footage, and the coordinate point with the fastest drilling speed, the coordinate system is divided into 4 regions. When dividing the shallow well section into zones, draw a rectangle in the coordinate system based on the coordinate points with the maximum footage and the fastest drilling speed. These two coordinate points are located at the upper left and lower right corners of the rectangle, respectively. Draw a first dividing line that passes through the coordinate points with the maximum footage and the fastest drilling speed. The triangle formed by the first dividing line, the left side of the rectangle, and the bottom edge of the rectangle is area I; Based on the average mechanical drilling rate, draw a second dividing line perpendicular to the drilling rate coordinate axis. The second dividing line intersects the top edge of the rectangle and the first dividing line. Draw a third dividing line parallel to the drilling rate coordinate axis and intersects the second dividing line and the first dividing line at the intersection. The triangle formed by the second dividing line, the first dividing line, and the top edge of the rectangle is area II; The triangle formed by the third dividing line, the first dividing line, and the right side of the rectangle is area II; Draw the fourth dividing line, which intersects the second dividing line at the intersection of the top edge of the rectangle and the third dividing line at the intersection of the right edge of the rectangle. The triangle formed by the second, third, and fourth dividing lines is zone III; The triangle formed by the fourth dividing line, the top edge of the rectangle, and the right edge of the rectangle is zone IV. In the coordinate system, from the lower left to the upper right, they are: Zone I, Zone II, Zone III, and Zone IV. Zone II consists of two parts, with the priority being: Zone IV > Zone III > Zone II > Zone I. When both are in Zone II, faster drilling speed is the second preferred indicator. For medium-deep and deep well sections, the average footage of the drill bit in the target formation is used as the main analysis index. Based on the average footage of the drill bit in the target formation, the coordinate point with the most footage, and the coordinate point with the fastest drilling speed, the coordinate system is divided into 4 regions. When dividing the medium-deep and deep well sections, draw a rectangle in the coordinate system based on the coordinate points with the maximum footage and the fastest drilling speed. These two coordinate points are located at the upper left and lower right corners of the rectangle, respectively. Draw a first dividing line that passes through the coordinate points with the maximum footage and the fastest drilling speed. The triangle formed by the first dividing line, the left side of the rectangle, and the bottom edge of the rectangle is area I; Based on the average drilling footage, draw a second dividing line parallel to the drilling speed coordinate axis. The second dividing line intersects with the first dividing line and the right side of the rectangle. Draw a third dividing line, which is perpendicular to the drilling speed coordinate axis and intersects with the intersection of the second dividing line and the first dividing line. The triangle formed by the third dividing line, the first dividing line, and the top edge of the rectangle is area II; The triangle formed by the second dividing line, the first dividing line, and the right side of the rectangle is area II; Draw the fourth dividing line, which intersects the third dividing line at the point where it intersects the top edge of the rectangle, and the second dividing line at the point where it intersects the right edge of the rectangle. The triangle formed by the second, third, and fourth dividing lines is zone III; The triangle formed by the fourth dividing line, the top edge of the rectangle, and the right edge of the rectangle is zone IV. In the coordinate system, from bottom left to top right, the zones are: Zone I, Zone II, Zone III, and Zone IV. Zone II consists of two parts, with the priority being: Zone IV > Zone III > Zone II > Zone I. When both are in Zone II, the longer advance length is taken as the second preferred indicator.

6. A computer device, comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that, When the processor executes the computer program, it implements the method of any one of claims 1 to 4.

7. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores a computer program that, when executed by a processor, implements the method of any one of claims 1 to 4.

8. A computer program product, characterized in that, The computer program product includes a computer program that, when executed by a processor, implements the method of any one of claims 1 to 4.

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