A method, system, storage medium, and apparatus for designing a PDC bit

Abstract

The application discloses a PDC bit design method, system, storage medium and equipment, acquires the lithology type of a target stratum depth, calculates the volume fraction of the rock at the same stratum depth; calculates the uniaxial compressive strength of different lithologies at the same stratum depth; calculates the comprehensive uniaxial compressive strength of the rock at the stratum depth based on the uniaxial compressive strength of each lithology and the volume fraction of the rock, calculates the grindability index and the impact index of the rock based on the obtained comprehensive uniaxial compressive strength of the rock, divides the grindability index and the impact index into different degree indexes, arranges and combines the division results, determines the stratum drillability of the PDC bit, obtains the design parameters of the PDC bit based on the obtained stratum drillability, improves the adaptability of the bit to different lithologies, can shorten the rock drilling time in the actual drilling process, improves the rock drilling speed, improves the overall rock breaking efficiency, the stability of the bit is higher, and the whole rock drilling cycle is shortened.

Description

Technical Field

[0001] This invention belongs to the field of petroleum exploration technology and relates to a PDC drill bit design method, system, storage medium and equipment. Background Technology

[0002] Diamond drill bits (also known as PDC drill bits) used in oil exploration drilling consist of a drill body made of steel that has undergone machining and heat treatment, and diamond composite cutting teeth brazed to the cutting edges of the drill bit's blades. In general, PDC drill bits use diamond composite teeth (PDC cutting teeth) deployed on the blades as cutting elements to cut the contacting formation, causing it to shear and fracture, thus achieving rock breaking. The hardness of the diamond composite teeth is several orders of magnitude higher than that of rock; therefore, in a stable cutting process, the rock always fails first, while the diamond composite teeth wear down slowly until their cutting edges are worn flat and unusable.

[0003] However, in the use of existing PDC drill bits, due to the lack of prior assessment of the damage to the drill bit caused by lithology, the drill bit design features cannot be selected according to different lithologies. As a result, PDC drill bits are often in an unstable state during drilling in different lithological formations. At this time, the damage to the diamond composite sheet manifests as both slow wear and impact damage due to drill bit instability. Summary of the Invention

[0004] The purpose of this invention is to solve the problem that existing technologies often result in PDC drill bits being in an unstable state because they do not pre-assess the damage to the drill bit caused by different lithologies and cannot select drill bit design features according to different lithologies. The invention provides a PDC drill bit design method, system, storage medium, and device. It performs rock physical modeling using raw measurement values ​​from well logging data, establishes a dual index of formation abrasiveness and formation impact, and determines the design parameters of the PDC drill bit based on the magnitude of the dual index. By pre-assessing the damage to the drill bit caused by different lithologies and selecting drill bit design parameters according to different lithologies, the stability of the PDC drill bit is improved.

[0005] To achieve the above objectives, the present invention employs the following technical solution: A PDC drill bit design method includes the following steps: S1: Obtain the lithological types at the same stratum depth and calculate the volume fraction of different lithologies at the same stratum depth; S2: Calculate the uniaxial compressive strength of rocks with different lithologies at the same stratum depth; S3: Calculate the comprehensive uniaxial compressive strength of rock at the same formation depth based on the uniaxial compressive strength of each lithology and the volume fraction of the lithology; S4: Calculate the abrasiveness index and impact index of the rock based on the obtained comprehensive uniaxial compressive strength of the rock; S5: Divide the obtained abrasiveness index and impact index, and arrange and combine the division results to determine the formation drillability of PDC drill bit; S6: Based on the formation drillability of the obtained PDC drill bit, obtain the design parameters of the PDC drill bit.

[0006] A further improvement of the present invention is that: Step S1 includes the following steps: Four different lithologies at the same stratigraphic depth were selected for analysis; P-wave DTC, gamma GR, neutron density RHOB, and porosity NPHI were collected for four different lithologies. The volume fractions of the four lithologies are calculated using equations (1)-(4):

[0007] In the formula, {i=1, 2, 3, 4} represents the gamma measurements obtained for four different lithologies. Indicates the preset gamma;

[0008] In the formula, , {i=1, 2, 3, 4}, represent the neutron densities of four different lithologies measured. Indicates the preset gamma;

[0009] In the formula, {i=1, 2, 3, 4} represents the longitudinal waves of four different lithologies measured. This indicates the preset longitudinal wave;

[0010] In the formula, , {i=1, 2, 3, 4}, represent the porosity of four different lithologies measured. Indicates the preset porosity; The , , and The following formula must be satisfied:

[0011] The four types of lithology selected in step S1 include: sandstone, shale, limestone, and dolomite.

[0012] Step S2 includes the following steps: The uniaxial compressive strength of the sandstone is calculated using equation (6):

[0013] The uniaxial compressive strength of the shale (7):

[0014] The uniaxial compressive strength of the limestone (8):

[0015] The uniaxial compressive strength of the dolomite (9):

[0016] In step S3, the method for calculating the comprehensive uniaxial compressive strength of rocks of each lithology at the same stratum depth is as follows: The uniaxial compressive strength of each lithology at the same stratum depth is multiplied by the volume fraction of that lithology.

[0017] Step S4 includes the following steps: The abrasiveness index is obtained by equation (10):

[0018] In the formula, V-sand represents the volume fraction of sandstone in the formation; UCS is the comprehensive uniaxial compressive strength of the rock at that formation depth; The impact index is obtained through equation (11):

[0019] In the formula, UCS is the comprehensive uniaxial compressive strength of the rock at that stratum depth; UCS-ave is the average value of the comprehensive uniaxial compressive strength per unit depth.

[0020] The design parameters of the PDC drill bit obtained in step S6 include: Crown profile, tooth size, number of blades, selection of limiting teeth, and selection of diameter preservation.

[0021] A PDC drill bit design system includes a volume fraction calculation module, a rock uniaxial compressive strength calculation module, a rock comprehensive uniaxial compressive strength calculation module, a duality index acquisition module, a formation drillability acquisition module, and a design parameter acquisition module; The volume fraction calculation module is used to obtain the lithology types at the same stratum depth and calculate the volume fraction of different lithologies at the same stratum depth. The uniaxial compressive strength calculation module for rocks is used to calculate the uniaxial compressive strength of rocks of different lithologies at the same stratum depth. The rock composite uniaxial compressive strength calculation module is used to calculate the rock composite uniaxial compressive strength at the same formation depth based on the rock uniaxial compressive strength of each lithology and the volume fraction of the lithology. The dual-activity index acquisition module is used to calculate the abrasiveness index and impact index of the rock based on the obtained comprehensive uniaxial compressive strength of the rock. The formation drillability acquisition module is used to classify the obtained abrasiveness index and impact index, and arrange and combine the classification results to determine the formation drillability of the PDC drill bit. The design parameter acquisition module is used to obtain the design parameters of the PDC drill bit based on the formation drillability obtained by the PDC drill bit.

[0022] A terminal device includes 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 the steps of any of the methods described in this invention.

[0023] A computer-readable storage medium storing a computer program that, when executed by a processor, implements the steps of any of the methods described in this invention.

[0024] Compared with the prior art, the present invention has the following beneficial effects: This invention discloses a PDC drill bit design method. It analyzes the lithology at the same formation depth using raw measurement data, establishes a dual index of formation abrasiveness and formation impact based on the analysis results, clarifies the drillable formation shape of the PDC drill bit according to the dual indexes, and determines the design parameters of the PDC drill bit based on the formation drillability. This method, through preliminary lithology analysis, can maximize the cutting and rock-breaking performance of the PDC drill bit for different lithologies, improve the adaptability of the PDC drill bit to lithologies at different formation depths, shorten drilling time, increase drilling speed, improve overall rock-breaking efficiency, enhance drill bit stability, reduce impact damage to the drill bit, and shorten the entire drilling cycle. Attached Figure Description

[0025] To more clearly illustrate the technical solutions of the embodiments of the present invention, the accompanying drawings used in the embodiments will be briefly introduced below. It should be understood that the following drawings only show some embodiments of the present invention and should not be regarded as a limitation on the scope. For those skilled in the art, other related drawings can be obtained based on these drawings without creative effort.

[0026] See Figure 1 This is a flowchart illustrating the design process of the present invention. Detailed Implementation

[0027] To make the objectives, technical solutions, and advantages of the embodiments of the present invention clearer, the technical solutions of the embodiments of the present invention will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. The components of the embodiments of the present invention described and shown in the accompanying drawings can generally be arranged and designed in various different configurations.

[0028] Therefore, the following detailed description of the embodiments of the invention provided in the accompanying drawings is not intended to limit the scope of the claimed invention, but merely to illustrate selected embodiments of the invention. All other embodiments obtained by those skilled in the art based on the embodiments of the invention without inventive effort are within the scope of protection of the invention.

[0029] It should be noted that similar labels and letters in the following figures indicate similar items. Therefore, once an item is defined in one figure, it does not need to be further defined and explained in subsequent figures.

[0030] In the description of the embodiments of the present invention, it should be noted that if terms such as "upper," "lower," "horizontal," or "inner" indicate the orientation or positional relationship based on the orientation or positional relationship shown in the accompanying drawings, or the orientation or positional relationship commonly used when the product of the invention is in use, they are only for the convenience of describing the present invention and simplifying the description, and do not indicate or imply that the device or element referred to must have a specific orientation, or be constructed and operated in a specific orientation, and therefore should not be construed as a limitation of the present invention. Furthermore, terms such as "first" and "second" are only used to distinguish descriptions and should not be construed as indicating or implying relative importance.

[0031] Furthermore, the use of the term "horizontal" does not imply that the component must be absolutely horizontal, but rather that it can be slightly tilted. For example, "horizontal" simply means that its direction is more horizontal than "vertical," and does not mean that the structure must be completely horizontal, but can be slightly tilted.

[0032] In the description of the embodiments of the present invention, it should also be noted that, unless otherwise explicitly specified and limited, the terms "set," "install," "connect," and "link" should be interpreted broadly. For example, they can refer to a fixed connection, a detachable connection, or an integral connection; they can refer to a mechanical connection or an electrical connection; they can refer to a direct connection or an indirect connection through an intermediate medium; and they can refer to the internal connection of two components. Those skilled in the art can understand the specific meaning of the above terms in the present invention according to the specific circumstances.

[0033] The present invention will now be described in further detail with reference to the accompanying drawings: See Figure 1This invention discloses a PDC drill bit design method. The target formation is qualitatively classified into up to four candidate lithologies based on cuttings logging data. The volume fraction of each candidate lithology is calculated using geophysical logging data, and the uniaxial compressive strength (UCS) of each lithology is calculated. Based on the uniaxial compressive strength and corresponding volume fraction of each lithology, the comprehensive uniaxial compressive strength (UCS) at that depth is calculated. Two indices, formation abrasiveness and impact resistance, are also calculated. Based on these two indices, the formations are categorized into four different levels of abrasiveness and impact resistance. 4. A total of 16 different PDC bit selection rules are defined, and the final PDC bit selection parameter combination for the well section is determined according to the target well section required for drilling.

[0034] The method disclosed in this invention includes the following steps: Step 1: Obtain the lithology at the target stratum depth and calculate the volume fraction of rocks at the same stratum depth; The embodiments of this invention establish the stratigraphic lithology at various depths based on cuttings logging. The methods disclosed in the embodiments of this invention cover the following lithologies: Mudstone, shale, sandstone, conglomerate, flint, igneous rocks, metamorphic rocks, volcanic eruptive rocks, limestone, dolomite, chalk limestone, gypsum rock, salt rock, pyrite, and coal.

[0035] Furthermore, using data obtained from geophysical logging techniques, including P-wave DTC, gamma ray GR, neutron density RHOB, and porosity NPHI, the volume fraction of rock components at the same depth was calculated.

[0036] Furthermore, the method disclosed in the embodiments of the invention can provide up to four different lithology options for the same depth, and then solve for their respective volume fractions according to the following set of equations:

[0037] In the formula, {i=1, 2, 3, 4} represents the gamma measurements obtained for four different lithologies. Indicates the preset gamma;

[0038] In the formula, , {i=1, 2, 3, 4}, represent the neutron densities of four different lithologies measured. Indicates the preset gamma;

[0039] In the formula, {i=1, 2, 3, 4} represents the longitudinal waves of four different lithologies measured. This indicates the preset longitudinal wave;

[0040] In the formula, , {i=1, 2, 3, 4}, represent the porosity of four different lithologies measured. This indicates the preset porosity.

[0041] Considering a unit rock, i.e., rock at the same stratum depth, as a whole, a unit rock can be defined by a maximum of four lithologies, each with a corresponding volume fraction. The sum of the volume fractions of the four different lithologies equals 1, which is the unit rock volume. Therefore, the volume fraction obtained through equations (1) to (4) is... , , and The following formula must be satisfied:

[0042] Step 2: Calculate the uniaxial compressive strength of different lithologies at the same stratum depth; This invention takes sandstone, shale, limestone, and dolomite at the same stratum depth as examples, and calculates the uniaxial compressive strength (UCS) of each lithology using different empirical formulas selected according to different lithologies: Uniaxial compressive strength of sandstone (Freyburg, 1972 empirical formula):

[0043] Uniaxial compressive strength of shale (Horsrud, 2001 empirical formula):

[0044] Uniaxial compressive strength of limestone (Militzer, 1973 empirical formula):

[0045] Uniaxial compressive strength of dolomite and other lithologies (Golubev, 1976 empirical formula):

[0046] Step 3: Based on the calculated uniaxial compressive strength (UCS) of a single lithology, calculate the comprehensive uniaxial compressive strength (UCS) of the rock at that depth according to its volume fraction. In this embodiment of the invention, the comprehensive uniaxial compressive strength of rock (UCS) is equal to the uniaxial compressive strength of rock (UCS) multiplied by the volume fraction at the same depth.

[0047] Step 4: Based on the comprehensive uniaxial compressive strength (UCS) of the rock obtained at various depths throughout the well section, calculate the abrasiveness index and impact index of the rock through normalization. The abrasiveness index is obtained by equation (10):

[0048] The impact index is obtained through equation (11):

[0049] Where V-sand is the volume fraction of sandstone in the strata, UCS is the comprehensive uniaxial compressive strength of the rock calculated at depth, and UCS-ave is the average value of the comprehensive uniaxial compressive strength calculated per unit depth.

[0050] Step 5: Divide the abrasiveness index and impact index into different degree indices, and arrange and combine the division results to determine the formation drillability of the PDC drill bit; In this embodiment of the invention, the abrasiveness index and the impact index are each divided into four different levels of index; Furthermore, based on the abrasiveness index and impact index of 4 The permutation and combination of four degree indices determine the formation drillability based on PDC drill bits; Furthermore, the design parameters of the PDC drill bit are quantitatively determined based on the obtained formation drillability results, as shown in Tables 1 to 5.

[0051] The design parameters of this invention include: crown profile, tooth size, number of blades, selection of limiting teeth, and selection of diameter retention.

[0052] Table 1 Number of blades

[0053] Table 2 Cutting tooth size

[0054] Table 3 Limiting teeth

[0055] Table 4 Crown Profile

[0056] L: Line; A: Arc; G: Gauge Table 5 Diameter Protection Design

[0057] TSP: Thermal Stable Polycrystalline Diamond Furthermore, in this embodiment of the invention, the PDC drill bit design index parameters obtained at each depth are summarized to quantitatively determine the overall drill bit selection result for the target well section (starting depth and ending depth).

[0058] Furthermore, based on the drillability analysis of the target dolomite formation, and combined with its impact and abrasive characteristics, the present invention takes the difficult-to-drill dolomite formation of the Qiulitag Formation in the Matan 1 well as an example. Its impact is medium to high and its abrasiveness is medium to high. Therefore, the optimal number of cutter wings is 6, the cutting tooth size is 13mm / 16mm, and any tooth with unlimited position is acceptable. The drill bit profile is LAAG type, with diamond gauge protection design. Finally, the ST616ZX PDC drill bit is determined to be the preferred drill bit for the dolomite formation in the target well section.

[0059] The drill bit was field-tested in the Qiulitag Formation of the Matan 1 well, achieving a single drill bit footage of 145m, a pure drilling time of 82.3h, and an average drill speed of 1.8m / h. The drill bit was eventually pulled out due to abnormal downhole torque caused by the vertical drilling tool. Compared with the average drill speed of the same section and lithology in the adjacent well, the drill bit increased the speed by 43%.

[0060] Taking the Cambrian dolomite in the 5 7 / 8″ section of the Tumu 1 well as an example, its impact resistance is medium to high and its abrasiveness is high. Therefore, the optimal selection is 7 cutter wings, 13mm / 16mm cutting tooth size, limiting teeth, LAAAG type drill bit profile, and diamond gauge design. The MT713ZX drill bit was finally selected as the preferred drill bit for the target well section. This drill bit was tested in the field in the Cambrian Wusonggeer Formation and other dolomite strata of the Tumu 1 well. It achieved a single drill bit footage of 158.85m, a pure drilling time of 101.5h, and an average drill speed of 1.56m / h. Compared with the average drill speed of the same section and lithology in adjacent wells, the speed was increased by 17%, achieving a good speed improvement effect.

[0061] The method disclosed in this invention can maximize the cutting and rock-breaking performance of the drill bit and improve the adaptability of the drill bit to the formation. By using well logging data to quantitatively characterize the formation drillability, key drill bit design parameters such as the number of drill bit blades, cutting tooth size, crown profile, limiting teeth, and gauge protection design can be quantitatively determined. Ultimately, the appropriate combination of PDC drill bit design and selection parameters for the target formation can be determined. This method has good application value for guiding the selection of suitable drill bits during actual drilling, improving rock-breaking efficiency, and shortening the drilling cycle.

[0062] A PDC drill bit design system, characterized in that it includes a volume fraction calculation module, a rock uniaxial compressive strength calculation module, a rock comprehensive uniaxial compressive strength calculation module, a duality index acquisition module, a formation drillability acquisition module, and a design parameter acquisition module; The volume fraction calculation module is used to obtain the lithology types at the same stratum depth and calculate the volume fraction of different lithologies at the same stratum depth. The uniaxial compressive strength calculation module for rocks is used to calculate the uniaxial compressive strength of rocks of different lithologies at the same stratum depth. The rock composite uniaxial compressive strength calculation module is used to calculate the rock composite uniaxial compressive strength at the same formation depth based on the rock uniaxial compressive strength of each lithology and the volume fraction of the lithology. The dual-activity index acquisition module is used to calculate the abrasiveness index and impact index of the rock based on the obtained comprehensive uniaxial compressive strength of the rock. The formation drillability acquisition module is used to classify the obtained abrasiveness index and impact index, and arrange and combine the classification results to determine the formation drillability of the PDC drill bit. The design parameter acquisition module is used to obtain the design parameters of the PDC drill bit based on the formation drillability obtained by the PDC drill bit.

[0063] The terminal device of this invention includes: a processor, a memory, and a computer program stored in the memory and executable on the processor.

[0064] When the processor executes the computer program, it implements the steps in the various method embodiments described above. Alternatively, when the processor executes the computer program, it implements the functions of each module / unit in the various device embodiments described above.

[0065] The computer program can be divided into one or more modules / units, which are stored in the memory and executed by the processor to complete the present invention.

[0066] The terminal device may be a desktop computer, laptop, handheld computer, or cloud server, etc. The terminal device may include, but is not limited to, a processor and a memory.

[0067] The processor may be a central processing unit (CPU), or other general-purpose processors, digital signal processors (DSPs), application-specific integrated circuits (ASICs), field-programmable gate arrays (FPGAs), or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, etc.

[0068] The memory can be used to store the computer program and / or module. The processor implements various functions of the terminal device by running or executing the computer program and / or module stored in the memory and calling the data stored in the memory.

[0069] If the modules / units integrated in the terminal device are implemented as software functional units and sold or used as independent products, they can be stored in a computer-readable storage medium.

[0070] Based on this understanding, the present invention can implement all or part of the processes in the methods of the above embodiments, or it can be accomplished by a computer program instructing related hardware. The computer program can be stored in a computer-readable storage medium, and when executed by a processor, it can implement the steps of the various method embodiments described above. The computer program includes computer program code, which can be in the form of source code, object code, executable files, or certain intermediate forms. The computer-readable medium can include: any entity or device capable of carrying the computer program code, a recording medium, a USB flash drive, a portable hard drive, a magnetic disk, an optical disk, a computer memory, a read-only memory (ROM), a random access memory (RAM), an electrical carrier signal, a telecommunication signal, and a software distribution medium, etc.

[0071] It should be noted that the content contained in the computer-readable medium may be appropriately added to or subtracted from the content as required by the legislation and patent practice in the jurisdiction. For example, in some jurisdictions, according to legislation and patent practice, the computer-readable medium may not include electrical carrier signals and telecommunication signals.

[0072] The above are merely preferred embodiments of the present invention and are not intended to limit the present invention. Various modifications and variations can be made to the present invention by those skilled in the art. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of the present invention should be included within the scope of protection of the present invention.

Claims

1. A PDC drill bit design method, characterized in that, Includes the following steps: S1: Obtain the lithological types at the same stratum depth and calculate the volume fraction of different lithologies at the same stratum depth; S2: Calculate the uniaxial compressive strength of rocks with different lithologies at the same stratum depth; S3: Calculate the comprehensive uniaxial compressive strength of rock at the same formation depth based on the uniaxial compressive strength of each lithology and the volume fraction of the lithology; S4: Calculate the abrasiveness index and impact index of the rock based on the obtained comprehensive uniaxial compressive strength of the rock; S5: Divide the obtained abrasiveness index and impact index, and arrange and combine the division results to determine the formation drillability of PDC drill bit; S6: Based on the formation drillability of the obtained PDC drill bit, obtain the design parameters of the PDC drill bit; Step S1 includes the following steps: Four different lithologies at the same stratigraphic depth were selected for analysis; P-wave DTC, gamma GR, neutron density RHOB, and porosity NPHI were collected for four different lithologies. The volume fractions of the four lithologies are calculated using equations (1)-(4): In the formula, {i=1, 2, 3, 4} represents the gamma measurements obtained for four different lithologies. Indicates the preset gamma; In the formula, , {i=1, 2, 3, 4}, represent the neutron densities of four different lithologies measured. Indicates the preset gamma; In the formula, {i=1, 2, 3, 4} represents the longitudinal waves of four different lithologies measured. This indicates the preset longitudinal wave; In the formula, , {i=1, 2, 3, 4}, represent the porosity of four different lithologies measured. Indicates the preset porosity; The , , and The following formula must be satisfied: The four types of lithology selected in step S1 include: sandstone, shale, limestone and dolomite; Step S2 includes the following steps: The uniaxial compressive strength of the sandstone is calculated using equation (6): The uniaxial compressive strength of the shale (7): The uniaxial compressive strength of the limestone (8): The uniaxial compressive strength of the dolomite (9): The design parameters of the PDC drill bit obtained in step S6 include: Crown profile, tooth size, number of blades, selection of limiting teeth, and selection of diameter preservation; In step S3, the method for calculating the comprehensive uniaxial compressive strength of rocks of each lithology at the same stratum depth is as follows: The uniaxial compressive strength of each lithology at the same stratum depth is multiplied by the volume fraction of that lithology. Step S4 includes the following steps: The abrasiveness index is obtained by equation (10): In the formula, V-sand represents the volume fraction of sandstone in the formation; UCS is the comprehensive uniaxial compressive strength of the rock at that formation depth; The impact index is obtained through equation (11): In the formula, UCS is the comprehensive uniaxial compressive strength of the rock at that stratum depth; UCS-ave is the average value of the comprehensive uniaxial compressive strength per unit depth.

2. The system of the PDC drill bit design method according to claim 1, characterized in that, It includes modules for calculating volume fraction, calculating uniaxial compressive strength of rock, calculating comprehensive uniaxial compressive strength of rock, obtaining bipolar index, obtaining formation drillability, and obtaining design parameters. The volume fraction calculation module is used to obtain the lithology types at the same stratum depth and calculate the volume fraction of different lithologies at the same stratum depth. The uniaxial compressive strength calculation module for rocks is used to calculate the uniaxial compressive strength of rocks of different lithologies at the same stratum depth. The rock composite uniaxial compressive strength calculation module is used to calculate the rock composite uniaxial compressive strength at the same formation depth based on the rock uniaxial compressive strength of each lithology and the volume fraction of the lithology; The dual-activity index acquisition module is used to calculate the abrasiveness index and impact index of the rock based on the obtained comprehensive uniaxial compressive strength of the rock. The formation drillability acquisition module is used to classify the obtained abrasiveness index and impact index, and arrange and combine the classification results to determine the formation drillability of the PDC drill bit. The design parameter acquisition module is used to obtain the design parameters of the PDC drill bit based on the formation drillability obtained by the PDC drill bit.

3. A terminal 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 steps of the method as described in claim 1.

4. A computer-readable storage medium storing a computer program, characterized in that, When the computer program is executed by a processor, it implements the steps of the method as described in claim 1.

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