Drill bit life prediction method, system, device and medium based on logging parameters

Abstract

The application provides a drilling bit life prediction method, system, device and medium based on mud logging parameters, the method comprising correcting drilling time according to the drilling bit wear rate of single-trip drilling of a target well and the footage drilled by the drilling bit; performing correlation analysis on the corrected drilling time and mud logging element data of a corresponding layer section of a geological section to obtain main wear participating elements of the corresponding layer section and calculate an energy index required for drilling through the stratum; calculating a wear coefficient of the corresponding layer section according to the stratum energy index of the layer section and the drilling bit wear rate of the footage of the corresponding layer section; and calculating the drilling bit wear degree according to the stratum energy index of the drilled layer section and the wear coefficient of the corresponding layer section to predict the service life of the drilling bit. The application has the advantages that the service life of the downhole drilling bit can be predicted in real time, invalid tripping is reduced, the drilling time efficiency of single-trip drilling is improved, and the drilling cost is saved.

Description

Technical Field

[0001] This invention relates to the field of oil and gas exploration and development technology, specifically to a method, system, equipment, and medium for predicting drill bit life based on logging parameters. Background Technology

[0002] In oil and gas exploration and development, improving drilling efficiency and reducing drilling costs have always been important issues of widespread concern. During drilling, the drill bit breaks through rock and also wears down. Worn drill bits reduce drilling speed, and frequent tripping in and out of the hole due to the inability to predict drill bit lifespan and assess wear levels further reduces drilling efficiency and increases costs. Therefore, optimizing drill bit usage, improving drill bit utilization, and predicting drill bit lifespan are key factors in improving drilling efficiency and saving costs.

[0003] Currently, most oilfields use an experience-based method to determine the service life of downhole drill bits. This method relies on the accumulated experience of drilling engineers regarding the service life of drill bits in a given area to judge the wear level of downhole drill bits. However, this method has a high error rate and is prone to misjudgment.

[0004] For example, the Chinese patent with application number "CN201380079643.3" entitled "Dynamic Wear Prediction of Drill Bits with Fixed Cutting Edges" partially calculates the final predicted wear profile of the cutting structure based on the unworn profile and the diamond distribution, which is inconsistent with the development trend of using PDC and other drill bits in China. Other Chinese patents, such as "CN202080043312.4" entitled "Method and System for Estimating Drill Bit Wear" and "CN201980027884.0" entitled "System and Method for Monitoring Drill Bit Wear," primarily rely on engineering parameters for downhole drilling. Methods for judging drill bit wear include Chinese patents with application numbers CN202110561777.5 and CN201910728790.8, which use a pre-set database to establish a drill bit wear grading table. Through image acquisition, geometric feature methods and local feature analysis are used to grade the degree of drill bit wear. However, these methods do not adequately consider the influence of formation lithology, treating different lithologies as uniformly affecting drill bit wear, making them less suitable for deep and ultra-deep wells drilling through multiple formations. Patent US6109368A, entitled "Method and System for Predicting the Performance of a Drilling System for a Given Formation," proposes a device for monitoring the performance of drilling system equipment based on a geological model. However, this device is expensive, complex, and unsuitable for current PDC drill bits.

[0005] Currently, there are no drill bit life prediction methods based on geological models in my country. In the Sichuan-Chongqing region, tripping in wells at depths of 1000-2000 meters results in delays of 6-10 hours, while tripping in wells at depths of 3000-4000 meters results in delays of 20-24 hours. Given this situation, the drill bit life prediction method, system, equipment, and media provided in this invention are of great significance. Summary of the Invention

[0006] In view of the shortcomings of the prior art, the purpose of this invention is to solve one or more problems existing in the prior art. For example, one objective of this invention is to provide a method and system for predicting drill bit lifespan using, but not limited to, element-based logging parameters.

[0007] To achieve the above objectives, the present invention provides a method for predicting drill bit life based on logging parameters. The method may include: performing drilling time correction based on the drill bit wear rate and the footage drilled in a single run of the target well; conducting correlation analysis using the corrected drilling time and logging element data of the corresponding geological sections to obtain the main wear-involving elements of the corresponding sections and calculate the energy index required to penetrate the formation; calculating the wear coefficient of the corresponding section based on the formation energy index and the drill bit wear rate of the corresponding section's footage; and calculating the degree of drill bit wear based on the formation energy index and the wear coefficient of the drilled section, thereby predicting the drill bit's lifespan.

[0008] According to one or more exemplary embodiments of one aspect of the present invention, the drilling time correction may include: compiling the drilling depth and number of trips for each trip of the target well; determining the bit wear rate for a single trip using the freshness data of the bit entering and exiting the well for each trip; and correcting the drilling time based on the bit wear rate for a single trip and the depth of the well drilled by the bit in that trip.

[0009] According to one or more exemplary embodiments of one aspect of the present invention, the step of correcting the drilling time based on the bit wear rate of a single trip and the well depth drilled by the bit in that trip may include: assuming the bit wear rate of the trip is w, the well section drilled by the trip is Δh, the original drilling time is ROP, and the corrected drilling time is ROP. w When the drilling trip is from well depth h1 to h k The corrected drilling time is:

[0010]

[0011] Wherein, ROP w Δh is the corrected drilling time per meter of the formation, in min; ROP is the original drilling time, in min; Δh is the inclination thickness of the formation, in m; w is the bit wear rate for this run, in %; Δh is the h k -h1; k is the drilling depth (in meters) after this drilling trip.

[0012] According to one or more exemplary embodiments of one aspect of the present invention, the main wear-involving elements may include Na, Fe, Si, Mg, Ca, Al, Ba, S, Mn and K.

[0013] According to one or more exemplary embodiments of one aspect of the present invention, calculating the energy index required to penetrate the formation may include: the total rock-breaking time and wear time required to penetrate the corresponding formation is the total energy index Q of that formation.

[0014]

[0015] Where Δh is the slope thickness of the layer, in meters; h1 is the top depth of the layer, in meters; ROP w is the calibration drilling time per meter of the layer, in min; k is the drilling depth of the drill bit after this run, in m.

[0016] According to one or more exemplary embodiments of one aspect of the present invention, the rock mineral content varies at different depths in different target wells, but the types of major wear-involving elements in the same region and the same stratum remain unchanged. The energy index required to drill per meter can be correlated with the major wear-involving elements x1, x2, ..., x s Establish a relation, where s is a positive integer. When s = 4,

[0017] Q j =ax1 + bx2 + cx3 + dx4 + e;

[0018] Among them, Q j denoted as the formation energy index for this layer; a, b, c, d, and e are constants; j represents the layer segment.

[0019] According to one or more exemplary embodiments of one aspect of the present invention, calculating the wear coefficient of the corresponding segment may include:

[0020]

[0021] Where m is the wear coefficient of the corresponding layer; Q j The formation energy index for the corresponding layer; w j This represents the drill bit wear rate for the corresponding section of drilling.

[0022] According to one or more exemplary embodiments of one aspect of the present invention, calculating the degree of drill bit wear may include:

[0023] w = m1Q1 + m2Q2 + ... + m j Q j ;

[0024] Where w represents the degree of drill bit wear; m1 represents the wear coefficient of the first section; Q1 represents the formation energy index of the first section; and j represents the section divided by the drilled sections in a single drilling run.

[0025] According to one or more exemplary embodiments of one aspect of the present invention, the service life of the drill bit can be divided into four stages: when the wear degree of the drill bit is 0, it is brand new and is judged to be usable in the well; when the wear degree of the drill bit is greater than 0 and less than 10%, it is slightly worn and is judged to be usable in the well; when the wear degree of the drill bit is greater than or equal to 10% and less than or equal to 20%, it is normal wear and is judged to be usable in the well; when the wear degree of the drill bit is greater than 20%, it is severely worn and is judged to be unusable.

[0026] Another aspect of the present invention provides a drill bit life prediction system based on logging parameters. The system may include a correction unit, a first calculation unit, a second calculation unit, and a third calculation unit connected in sequence, with the first calculation unit connected to the third calculation unit. The correction unit is configured to perform drilling time correction based on the drill bit wear rate and the footage drilled in a single run of the target well. The first calculation unit is configured to perform correlation analysis using the corrected drilling time and logging element data of the corresponding geological segments to obtain the main wear-involving elements of the corresponding segments and calculate the energy index required to penetrate the formation of the segment. The second calculation unit is configured to calculate the wear coefficient of the corresponding segment based on the formation energy index and the drill bit wear rate of the corresponding segment's footage. The third calculation unit is configured to calculate the degree of drill bit wear based on the formation energy index of the drilled segment and the wear coefficient of the corresponding segment, thereby predicting the drill bit life.

[0027] Another aspect of the present invention provides a computer device, the computer device comprising: at least one processor; and a memory storing program instructions, wherein the program instructions are configured to be executed by the at least one processor, the program instructions including instructions for performing the drill bit life prediction method based on logging parameters according to any one of the preceding claims.

[0028] Another aspect of the present invention provides a computer-readable storage medium having stored thereon computer program instructions, which, when executed by a processor, can implement the drill bit life prediction method based on logging parameters as described in any one of the above claims.

[0029] Compared with the prior art, the beneficial effects of the present invention include at least one of the following:

[0030] (1) The drill bit life prediction method based on logging parameters proposed in this invention proposes to remove the drilling time correction content of drill bit newness, taking into account the different lithologies and rock-forming minerals of different formations.

[0031] (2) The drill bit life prediction method based on logging parameters proposed in this invention takes into account the influence of logging elements on drilling time and drill bit life, and proposes an energy index that can quantitatively show the drilled section and match the degree of drill bit wear.

[0032] (3) The method or system of the present invention can realize real-time prediction of the service life of downhole drill bits, reduce ineffective tripping, improve drilling efficiency of a single trip, and save drilling costs.

[0033] (4) This invention solves the problem of varying rock mineral content in different wells, different layers and different depths. It can effectively predict the wear degree of drill bit through logging parameters, predict the service life of drill bit, prevent overloading of drill bit, reduce ineffective tripping, and has good application effect. Attached Figure Description

[0034] The above and other objects and features of the present invention will become clearer from the following description taken in conjunction with the accompanying drawings, in which:

[0035] Figure 1 A flowchart illustrating the drill bit life prediction method based on logging parameters of the present invention is shown.

[0036] Figure 2A The diagram shows a partial correlation analysis of the corrected drilling time and the logging element Ba of the formation in Example 1.

[0037] Figure 2B The diagram shows a partial correlation analysis of the corrected drilling time and the logging element Ca of the formation in Example 1. Detailed Implementation

[0038] The present invention’s method, system, device and medium for predicting drill bit life based on logging parameters will be described in detail below with reference to the accompanying drawings and exemplary embodiments.

[0039] In the description of this application, it should be understood that the terms "first," "second," "third," etc., are merely for convenience of description and distinction, and should not be construed as indicating or implying relative importance or implicitly specifying the number of indicated technical features. Therefore, features defined with "first," "second," "third," etc., may explicitly or implicitly include one or more of that feature. In the description of this invention, unless otherwise stated, "a plurality of" or "several" means two or more. The terms "S1," "S2," "S3," "S4," etc., used in this invention are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. In the description of this application, it should be noted that, unless otherwise explicitly specified and limited, the terms "connected" or "linked" should be interpreted broadly. For example, it can refer to a fixed connection, a detachable connection, or an integral connection; it can refer to a direct connection or an indirect connection through an intermediate medium; it can refer to the internal connection of two elements. Those skilled in the art can understand the specific meaning of the above terms in this invention based on the specific circumstances.

[0040] Exemplary Example 1

[0041] like Figure 1 As shown, the drill bit life prediction method based on logging parameters mainly includes: correcting the drilling time for the wear rate and footage of drilled wells in the area; using correlation analysis to determine the main wear-involved elements in the formation; calculating the energy index required to penetrate the formation; calculating the wear coefficient of the formation based on the formation energy index and the drill bit wear rate of the footage; calculating the degree of drill bit wear based on the energy index and wear coefficient of the drilled section; and predicting the drill bit life.

[0042] Specifically, the drill bit life prediction method based on logging parameters in this exemplary embodiment may include the following steps:

[0043] S1. Drilling time correction is performed based on the drill bit wear rate and the footage drilled by the drill bit in a single trip of the target well.

[0044] S2. Using the logging element data of the corresponding geological segments and the corrected drilling time, conduct correlation analysis to obtain the main wear-involved elements of the corresponding segments and calculate the energy index required to drill through the formation of the segment.

[0045] S3. Calculate the wear coefficient of the corresponding layer based on the formation energy index of the layer and the drill bit wear rate of the corresponding layer footage.

[0046] S4. Calculate the degree of drill bit wear based on the formation energy index and wear coefficient of the drilled section, and predict the service life of the drill bit.

[0047] In this exemplary embodiment, step S1, drilling time correction may include the following steps:

[0048] ① Compile the drilling depth and number of trips for each trip of the research well (target well) (the number of trips or trips are data recorded on-site during drilling).

[0049] ② Use the freshness data of each drill bit entering and exiting the well to determine the wear rate of a single drill bit.

[0050] ③ Based on the drill bit wear rate and the well depth drilled in this trip, the drilling time is corrected. Let the drill bit wear rate be w, the well section drilled in this trip be Δh, the original drilling time be ROP, and the corrected drilling time be ROP. w When the drilling trip is from well depth h1 to h k The corrected drilling time is:

[0051]

[0052] In the formula, ROP w Δh is the corrected drilling time per meter of the formation, in min; ROP is the original drilling time, in min; Δh is the inclination thickness of the formation, in m; w is the bit wear rate for this run, in %; Δh is the h k -h1; k is the drilling depth (in meters) after this drilling trip.

[0053] By using the freshness data of each drill bit entering and exiting the well to determine the wear rate w of a single trip, the average wear rate per meter can be calculated.

[0054]

[0055] In this exemplary embodiment, step S2, determining the main wear-involving elements of each segment based on the correlation coefficient and calculating the energy index required to drill through that segment of the formation may include the following steps:

[0056] ① Adjust the drilling time ROP after correcting for the current well depth w The logging element data of that meter were matched and segmented according to different strata and sedimentary facies (this segmentation is a geological segmentation).

[0057] ② Conduct correlation analysis between the calibrated drilling time and the logging element data of this formation to obtain the main elements affecting the drilling time in this formation, i.e., the elements involved in drill bit wear, denoted as x1, x2, ... x s , where s is a positive integer.

[0058] ③The total rock-breaking time and wear time required to drill through this stratum, after removing the drill bit freshness coefficient, are set as the total energy index Q of the stratum, i.e.:

[0059]

[0060] In the formula, Q is the total energy index of the layer; Δh is the slope thickness of the layer, in meters; h1 is the top depth of the layer, in meters; ROP w is the calibration drilling time per meter of the layer, in min; k is the drilling depth of the drill bit after this run, in m.

[0061] ④ Because the rock mineral content varies at different depths in different wells, but the main wear-contributing elements in the same area and the same stratum remain unchanged, the energy index Q required to drill through that stratum will be... j Establish relationships with key wear-affected elements, for example:

[0062] Q j = ax1 + bx2 + cx3 + dx4 + e.

[0063] In the formula, Q j denoted as the formation energy index for this layer; a, b, c, d, and e are constants; j represents the layer segment.

[0064] In this exemplary embodiment, Q is the total energy index for drilling to that depth. j Let Q be the energy index of a certain segment. j The sum of .

[0065] In this exemplary embodiment, in step S2, the main wear-related elements may include Na, Fe, Si, Mg, Ca, Al, Ba, S, Mn, and K, etc.

[0066] In this exemplary embodiment, calculating the wear coefficient of the formation based on the formation energy index and the drill bit wear rate of the segment in step S3 may include the following steps:

[0067] Based on existing drilling data, combined with sedimentary and lithological characteristics, the strata traversed during this drilling operation were segmented (geological segmentation), and Q was obtained according to the above steps. j And the corresponding drill bit wear rate w obtained at the work site. j The energy index Q required to drill through this section of the formation. j With w j Establishing a relationship, that is:

[0068]

[0069] In the formula, m is the wear coefficient of the corresponding layer; Q j The formation energy index for the corresponding layer; w j This represents the drill bit wear rate for the corresponding section of drilling.

[0070] In this exemplary embodiment, in step S4, the degree of drill bit wear is calculated using the energy index and wear coefficient of the drilling section during active drilling, and the drill bit service life is predicted. Specifically, this may include the following steps:

[0071] ① Based on previous research and analysis, drill bit life is divided into four stages, as shown in Table 1:

[0072] Table 1. Drill Bit Wear Comparison Table

[0073]

[0074] Note: ● indicates that the well can be put into use and continue to operate; ○ indicates that it cannot be used.

[0075] ② Perform geological segmentation of the strata already drilled during the current drilling run.

[0076] ③ Calculate the energy index of this meter by using the main wear-affected elements per meter of the well logging data:

[0077] Q j =a j x1+b j x2+c j x3+d j x4+e.

[0078] In the formula, Q j This represents the formation energy index for this section; x1, x2, x3, and x4 are the logging values ​​of the main wear-affected elements per meter; a j b j c j d j Let be the corresponding constant of the relational expression for the j-th segment.

[0079] The total energy index of the formation penetrated after this drilling operation was obtained:

[0080]

[0081] In the formula, Q is the total energy index; j is the layer number (layer segment number); Q k is the energy index per meter of this layer; k is the drilling depth of the drill bit after this run.

[0082] It should be noted that this refers to the different wear coefficients m calculated from the drilled wells in the region (based on lithology and sedimentary sections). j Then, in a drilling rig, after changing the drill bit once, the drill bit is run down and drills into the formation, passing through one or more layers of the formation. Then, the previously calculated m is used... j The wear level of the drill bit is calculated by multiplying it by the energy index (which is related to the drilling footage) and then using Table 1 to determine whether the drill bit can continue to be used.

[0083] ④ Calculate the degree of drill bit wear using the wear coefficients of different layers:

[0084] w = m1Q1 + m2Q2 + ... + m j Q j .

[0085] In the formula, w represents the degree of drill bit wear; m1 represents the wear coefficient of the first section; Q1 represents the formation energy index of the first section; and j represents the section divided by the drilled sections in a single drilling run.

[0086] ⑤ The value of w can be used to determine the degree of drill bit wear. By referring to the drill bit wear level table (Table 1), it can be determined whether the drill bit can continue drilling, thus determining the service life of the drill bit.

[0087] Exemplary Example 2

[0088] This exemplary embodiment provides a drill bit life prediction system based on logging parameters.

[0089] The drill bit life prediction system based on logging parameters of this exemplary embodiment can realize the drill bit life prediction method based on logging parameters of exemplary embodiment 1.

[0090] The drill bit life prediction system based on logging parameters in this exemplary embodiment mainly includes a correction unit, a first calculation unit, a second calculation unit, and a third calculation unit connected in sequence, and the first calculation unit is connected to the third calculation unit.

[0091] The system comprises three main components: a calibration unit configured to perform drilling time calibration based on the drill bit wear rate and the footage drilled in a single run of the target well; a first calculation unit configured to perform correlation analysis using the calibrated drilling time and logging element data of the corresponding geological segments to obtain the main wear-involved elements of the corresponding segments and calculate the energy index required to penetrate the formation; a second calculation unit configured to calculate the wear coefficient of the corresponding segment based on the formation energy index and the drill bit wear rate of the corresponding segment; and a third calculation unit configured to calculate the degree of drill bit wear based on the formation energy index and the wear coefficient of the drilled segment, thereby predicting the lifespan of the drill bit.

[0092] To better understand the exemplary embodiments of the present invention described above, further explanation is provided below with reference to specific examples.

[0093] Example 1

[0094] Taking the W well area as an example, the drill bit life is predicted.

[0095] (1) Collect the drill bit wear rate and the drilling footage of the drilled well A1 in the well area, and correct the drilling time accordingly.

[0096] ① Collect and study the drilling depth and number of trips for each well trip.

[0097] ② Let the wear rate of this drill bit be w, the well section drilled in this run be Δh, and the original drilling time be ROP. Use the freshness data of the drill bit entering and exiting the well for each run to determine the wear rate w of a single run, and calculate the average wear rate per meter.

[0098]

[0099] Table 2A1 Well Drill Bit Usage Statistics (Excerpt)

[0100]

[0101] ③ Based on the drill bit wear rate and the well depth drilled in this trip, the drilling time is adjusted accordingly:

[0102]

[0103] (2) Use correlation analysis to determine the main wear-related elements in the stratum and calculate the energy index required to drill through the stratum.

[0104] ①Based on the sedimentary and lithological characteristics combined with the strata drilled through, the whole well calibration drilling time data is divided into 8 segments.

[0105] ② Correlation analysis was conducted using the corrected drilling time and the logging element data of the formation to obtain the main elements affecting drilling time in that formation, i.e., those involved in drill bit wear, which can be designated as x1, x2, x3, and x4. The correlation analysis of some of the main wear-involving elements, Ba and Ca, is shown in [reference needed]. Figures 2A-2B .

[0106] ③The total rock-breaking time and wear time required to drill through this formation, after removing the drill bit freshness coefficient, are set as the total energy index Q of this formation, i.e.:

[0107]

[0108] The main wear-related elements and the total energy index of the corresponding sections of well A1 can be obtained (Table 3).

[0109] Table 3. Statistics of major wear-involving elements and total energy index for each section of Well A1.

[0110]

[0111] ④ Because the rock mineral content varies at different depths in different wells, but the main wear-involving elements in the same area and the same section remain unchanged, the energy index Q required to drill through the section is correlated with the main wear-involving elements x1, x2, x3 and x4.

[0112] For example, the energy index for segment 6 is:

[0113] Q6=2.939Fe+2.561Ba+2.652Al+0.798Ca-26.423.

[0114] The wear coefficient for segment 6 is:

[0115]

[0116] This example uses a drilled well, and the wear degree of the drill bit in different sections has been calculated in Table 2. Here, we take the sixth section as an example to calculate the drill bit wear coefficient for this type of lithology and sediment. However, a drill bit may drill through more than one section, so when predicting new wells, it is necessary to accumulate the sections drilled by this drill bit and compare the total wear degree with Table 1 for judgment.

[0117] (3) Based on the energy index of each section in the W well area, the prediction of the wear degree of the drill bit during this drilling trip needs to be based on the sections drilled, the main wear-involved elements of each layer, and the wear coefficient of each layer to calculate the wear degree of the drill bit:

[0118] w = m1Q1 + m2Q2 + ... + m j Q j .

[0119] When w ≥ 20%, the drill bit is considered to have exhausted its lifespan, and it is recommended to pull out of the hole.

[0120] The drill bit life prediction method based on logging parameters according to the present invention can be programmed into a computer program and the corresponding program code or instructions can be stored in a computer-readable storage medium. When the program code or instructions are executed by a processor, the processor performs the above-described drill bit life prediction method based on logging parameters. The processor and memory can be included in a computer device.

[0121] Exemplary Example 3

[0122] This exemplary embodiment provides a computer-readable storage medium storing a computer program. The computer-readable storage medium stores a computer program that, when executed by a processor, causes the processor to perform a drill bit life prediction method based on logging parameters according to the present invention. The computer-readable recording medium is any data storage device capable of storing data read by a computer system. Examples of computer-readable recording media include: read-only memory, random access memory, read-only optical disk, magnetic tape, floppy disk, optical data storage device, and carrier waves (such as data transmission via the Internet through wired or wireless transmission paths).

[0123] Exemplary Example 4

[0124] An exemplary embodiment also provides a computer device. The computer device includes a processor and a memory. The memory stores a computer program. The computer program is executed by the processor, causing the processor to perform the computer program of the drill bit life prediction method based on logging parameters according to the present invention.

[0125] In summary, the beneficial effects include:

[0126] This invention provides a method, system, equipment, and medium for predicting drill bit life based on logging parameters, primarily applied in the field of oil and gas exploration and development. Accurately predicting drill bit life is crucial for improving drilling efficiency and reducing drilling costs. During drilling, the drill bit breaks rocks and wears down, reducing drilling speed. Frequent tripping in and out of the well due to the inability to predict drill bit life and assess wear also reduces drilling efficiency and increases costs. Therefore, optimizing drill bit usage, improving drill bit utilization, and predicting drill bit life are key factors for improving drilling efficiency and saving costs. Previous drill bit life prediction methods have insufficient consideration of the influence of formation lithology, treating different lithologies as having a uniform effect on drill bit wear, and lacking applicability to deep and ultra-deep wells drilling through multiple strata. This invention normalizes the wear degree of different drill bits under different formations, removing the influence of drill bit newness, and establishes a total energy index characterizing the total rock breaking time and wear time required to drill through the formation. It establishes a relationship between the energy index required to drill through each meter of each formation and the main wear-related elements, solving the problem of varying rock mineral content at different depths and in different formations of different wells. It effectively predicts the degree of drill bit wear using logging parameters, thereby predicting the lifespan of the drill bit.

[0127] Although the invention has been described above in conjunction with exemplary embodiments, those skilled in the art will understand that various modifications and changes can be made to the exemplary embodiments of the invention without departing from the spirit and scope defined by the claims.

Claims

1. A method for predicting drill bit life based on logging parameters, characterized in that, The method includes: Drilling time correction is performed based on the drill bit wear rate and the footage drilled by the drill bit in a single trip of the target well. Correlation analysis was conducted using logging element data from the corresponding geological sections and the corrected drilling time to obtain the main wear-involved elements in the corresponding sections and to calculate the energy index required to penetrate the formation of the section. The wear coefficient of the corresponding layer is calculated based on the formation energy index of the layer and the drill bit wear rate of the corresponding layer footage. The wear degree of the drill bit is calculated based on the formation energy index of the drilled section and the wear coefficient of the corresponding section, and the service life of the drill bit is predicted.

2. The drill bit life prediction method based on logging parameters according to claim 1, characterized in that, The drilling time correction includes: Compile the drilling depth and number of trips for each well trip targeting the target well; The wear rate of a single drill bit is determined by using the freshness data of each drill bit entering and exiting the well. The drilling time is adjusted based on the wear rate of the drill bit in a single trip and the depth of the well drilled in that trip.

3. The drill bit life prediction method based on logging parameters according to claim 2, characterized in that, The method of correcting the drilling time based on the bit wear rate of a single trip and the well depth drilled in that trip includes: assuming the bit wear rate of that trip is w, the well section drilled in that trip is Δh, the original drilling time is ROP, and the corrected drilling time is ROP. w When the drilling trip is from well depth h1 to h k The corrected drilling time is: Wherein, ROP w Δh is the corrected drilling time per meter of the formation, in min; ROP is the original drilling time, in min; Δh is the inclination thickness of the formation, in m; w is the bit wear rate for this run, in %; Δh is the h k -h1; k is the drilling depth (in meters) after this drilling trip.

4. The drill bit life prediction method based on logging parameters according to claim 1, characterized in that, The main wear-involving elements include Na, Fe, Si, Mg, Ca, Al, Ba, S, Mn, and K.

5. The method for predicting drill bit life based on logging parameters according to claim 1, characterized in that, The calculation of the energy index required to penetrate the formation includes: the total rock-breaking time and wear time required to penetrate the corresponding formation is the total energy index Q of that formation. Where Δh is the slope thickness of the layer, in meters; h1 is the top depth of the layer, in meters; ROP w is the calibration drilling time per meter of the layer, in min; k is the drilling depth of the drill bit after this run, in m.

6. The method for predicting drill bit life based on logging parameters according to claim 1, characterized in that, The rock mineral content varies at different depths in different target wells, but the types of major wear-involving elements in the same region and the same stratum remain unchanged. The energy index required to drill per meter is compared with the major wear-involving elements x1, x2, ..., x... s Establish a relation, where s is a positive integer. When s = 4, Q j =ax1+bx2+cx3+dx4+e; Among them, Q j denoted as the formation energy index for this layer; a, b, c, d, and e are constants; j represents the layer segment.

7. The method for predicting drill bit life based on logging parameters according to claim 1, characterized in that, The calculation of the wear coefficient for the corresponding layer includes: Where m is the wear coefficient of the corresponding layer; Q j The formation energy index for the corresponding layer; w j This represents the drill bit wear rate for the corresponding section of drilling.

8. The method for predicting drill bit life based on logging parameters according to claim 1, characterized in that, The calculation of drill bit wear includes: w=m1Q1+m2Q2+.......+m j Q j ; Where w represents the degree of drill bit wear; m1 represents the wear coefficient of the first section; Q1 represents the formation energy index of the first section; and j represents the section divided by the drilled sections in a single drilling run.

9. The method for predicting drill bit life based on logging parameters according to claim 1, characterized in that, The service life of the drill bit is divided into four stages: when the wear degree is 0, it is considered brand new and can be used in the well; when the wear degree is greater than 0 and less than 10%, it is considered slightly worn and can be used in the well; when the wear degree is greater than or equal to 10% and less than or equal to 20%, it is considered normal wear and can be used in the well; when the wear degree is greater than 20%, it is considered severely worn and cannot be used.

10. A drill bit life prediction system based on logging parameters, characterized in that, The system includes a correction unit, a first calculation unit, a second calculation unit, and a third calculation unit connected in sequence, with the first calculation unit and the third calculation unit connected together; wherein, The correction unit is configured to perform drilling time correction based on the bit wear rate and the footage drilled by the bit in a single trip of the target well; The first calculation unit is configured to conduct correlation analysis using the logging element data of the corresponding geological segment and the corrected drilling time to obtain the main wear-involved elements of the corresponding segment and calculate the energy index required to drill through the formation of the segment. The second calculation unit is configured to calculate the wear coefficient of the corresponding layer based on the formation energy index of the layer and the drill bit wear rate of the corresponding layer footage. The third calculation unit is configured to calculate the degree of drill bit wear based on the formation energy index of the drilled section and the wear coefficient of the corresponding section, and to predict the service life of the drill bit.

11. A computer device, characterized in that, The computer device includes: At least one processor; and A memory storing program instructions configured to be executed by the at least one processor, the program instructions including instructions for executing the drill bit life prediction method based on logging parameters according to any one of claims 1 to 9.

12. A computer-readable storage medium having computer program instructions stored thereon, characterized in that, When the computer program instructions are executed by the processor, they implement the drill bit life prediction method based on logging parameters as described in any one of claims 1 to 9.

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