Measurement system and calculation method for drilling speed of machinery while drilling

Abstract

The invention relates to the technical field of mechanical drilling speed measurement of directional drilling tools, in particular to a while-drilling mechanical drilling speed measurement system and a calculation method, and the while-drilling mechanical drilling speed measurement system comprises a mechanical drilling speed measurement body arranged in a hollow external drill collar. The mechanical drilling speed measuring body is connected with a measuring contact through an elastic device, and the measuring contact extends out of an external drill collar in the radial direction of the external drill collar. The two groups of measuring contacts are respectively a near-bit measuring group and a far-bit measuring group; each of the near-bit measuring group and the far-bit measuring group comprises two measuring contacts, the two measuring contacts in the near-bit measuring group and the far-bit measuring group are symmetrically arranged, and the two measuring contacts in the near-bit measuring group and the far-bit measuring group are correspondingly arranged; the method has important significance in the fields of petroleum drilling and the like in improving the drilling efficiency and reducing the drilling cost.

Description

Technical Field

[0001] This invention relates to the field of mechanical drilling rate measurement technology for directional drilling tools, specifically to a mechanical drilling rate measurement system and calculation method. Background Technology

[0002] Improving drilling efficiency and reducing drilling costs are important research topics in the oil drilling field. Mechanical rate of penetration (MRP) is one of the key indicators for evaluating drilling efficiency; accurate RPP measurement allows drilling personnel to make accurate judgments about drilling trends based on tool orientation characteristics.

[0003] Traditional methods for measuring mechanical drilling speed rely on ground-based measured data, empirical formulas, and simplified physical models. The core of these methods involves calculating the drilling speed by measuring parameters such as time, footage, drilling pressure, and rotational speed during the drilling process. Alternatively, the mechanical drilling speed can be calculated by the ratio of the drilling depth to the time taken down the drill string on the ground.

[0004] Traditional mechanical rotation speed measurement methods have limitations. For example, empirical formula methods rely on data from specific formations or regions, have poor universality, are not direct measurements, and result in inaccurate calculations. Methods that use the ratio of drilling depth to time often rely on manual recording, which is easily affected by operational delays or degree errors. Furthermore, the expansion and contraction of the downhole drill string due to stress or temperature can affect the accuracy and efficiency of the measurement. Summary of the Invention

[0005] This invention provides a drilling speed measurement system and calculation method that solves the problems of inaccurate measurement and poor method universality faced by existing mechanical drilling speed measurement methods such as indirect prediction, empirical formulas or manual measurement at the wellhead.

[0006] The present invention provides a mechanical drilling rate measurement system, comprising a mechanical drilling rate measurement body disposed inside a hollow outer drill collar, wherein the mechanical drilling rate measurement body is connected to a measuring contact via an elastic device, and the measuring contact extends radially from the outer drill collar. The measuring contacts are configured in two groups: a near-bit measuring group and a far-bit measuring group. Both the near-bit measurement group and the far-bit measurement group include two measuring contacts. The two measuring contacts in the near-bit measurement group and the far-bit measurement group are symmetrically arranged, and the two measuring contacts in the near-bit measurement group and the far-bit measurement group are correspondingly arranged. Each measuring contact is equipped with a displacement measuring device at the position corresponding to the mechanical drilling speed measuring body, which is used to measure and collect displacement data of the measuring contact as it approaches or moves away from the mechanical drilling speed measuring body; Also includes: The main control module is used to receive data transmitted by the displacement measuring device and perform calculations. All displacement measuring devices are connected to the main control module.

[0007] Preferably, the main control module includes an analog-to-digital conversion unit, a mechanical drilling speed calculation unit, and a communication unit that are connected in sequence. The displacement measuring devices are all electrically connected to the analog-to-digital conversion unit and connected to the communication unit.

[0008] Preferably, the outer drill collar is provided with the same number of protruding holes as the measuring contacts, a portion of the measuring contacts protruding from the protruding holes and protruding from the outer peripheral surface of the outer drill collar, and the portion of the measuring contacts protruding from the outer peripheral surface of the outer drill collar is curved.

[0009] Preferably, the elastic device is a return spring.

[0010] Preferably, the displacement measuring device is a magnetostrictive displacement sensor.

[0011] A method for measuring and calculating the rate of drilling while drilling (MOD) employs a MOD measurement system for the calculation. The method is as follows: A mechanical drilling rate measurement system is installed in the bottom drill string assembly, ensuring that the distance between the apex of the measuring contacts in the near-bit measurement group and the far-bit measurement group is greater than the drill bit diameter; that is, the distance between the ends of the measuring contacts in the near-bit measurement group and the far-bit measurement group that are furthest from each other is greater than the drill bit diameter. The drill bit drills at a certain drilling speed. The measuring contacts in both the near-bit and far-bit measuring groups extend out of the external drill collar and contact the well wall. During the operation of the drill bit, the measuring contacts in the near-bit measuring group and the far-bit measuring group will generate continuous displacements toward or away from the mechanical drilling speed measuring body according to the concavity and convexity of the well wall. The displacement measuring device continuously outputs an electrical signal of the measured contact displacement based on the continuous displacement generated by the measuring contact, and transmits it to the analog-to-digital conversion unit of the main control module. After signal sampling, it is input into the mechanical drilling speed calculation unit for mechanical drilling speed calculation. The mechanical drilling rate is obtained by using the ratio of the installation distance of the corresponding measuring contacts in the near-bit measurement group and the far-bit measurement group to the time it takes for the corresponding measuring contacts in the near-bit measurement group and the far-bit measurement group to pass through the same position on the well wall. The obtained mechanical drilling speed is transmitted to external equipment using a communication unit.

[0012] Preferably, the specific process of the mechanical drilling rate calculation unit performing mechanical drilling rate calculation is as follows: The mechanical drilling rate calculation unit processes the two measuring contacts of the near-bit measurement group over a time period. T The displacement data recorded inside is used to draw a curve to obtain the contour curve of the well wall, which is the initial contour curve. The mechanical drilling rate calculation unit processes the two measuring contacts of the far-bit measurement group over a time period. T The displacement data recorded inside the well is used to draw a curve to obtain the well wall profile curve, which is the final profile curve. The initial and final contour curves are recorded and saved by the main control module, and the Euclidean distance method is used to compare the initial and final contour curves. The measuring contacts in the near-bit measurement group and the far-bit measurement group store the same number of data points, and the data stored by each measuring contact are normalized to eliminate differences in dimensions and amplitude. Calculate the Euclidean distance for each corresponding point on each curve; The wellbore curve data obtained from the two measuring contacts in the near-bit measurement group are set for each group to collect data. Each data point is saved to the main control module, and the time is recorded as follows: ; Based on the wellbore curve data obtained from the two measuring contacts in the far-bit measurement group during the drilling process, each group is also set to collect data. There are 10 data points at this time. The data follows a first-in, first-out (FIFO) rule, meaning that sampling is complete. After the first data point, the newly sampled first... The next data point will become the latest data point, while the first data point will be overwritten, and so on. The Euclidean distance between corresponding measuring contacts in the near-bit and far-bit measurement groups was calculated, and the similarity was obtained. and ; The smaller the calculated Euclidean distance, the higher the similarity between the two curves. Curve similarity is calculated using the following formula. Conversion calculation; ; As the two measuring contacts in the far-end measuring group pass through the two measuring contacts in the near-end measuring group, data is collected. When this section of the well wall at each point, and At the same time, the similarity to the wellbore curve is greater than the threshold, and this moment is counted as... ; when and When the wellbore curve similarity threshold is met, and it is known that... , The installation distance between the corresponding measuring contacts in the near and far drill bit measurement groups and the far drill bit measurement group is: Then, the mechanical drilling rate at this time is: .

[0013] Traditional mechanical rotation speed measurement methods have limitations. For example, empirical formula methods rely on data from specific formations or regions, have poor universality, are not direct measurements, and result in inaccurate calculations. Methods that use the ratio of drilling depth to time often rely on manual recording, which is easily affected by operational delays or degree errors. Furthermore, the expansion and contraction of the downhole drill string due to stress or temperature can affect the accuracy and efficiency of the measurement.

[0014] This invention addresses the limitations of traditional mechanical drilling rate (MRR) measurement methods, which rely on ground-based measured data, empirical formulas, and simplified physical models. It designs a downhole mechanical drilling rate (MRR) measurement method and device to directly measure the MMR and broadcast the measurement and calculation results. MMR is a crucial indicator for evaluating drilling efficiency; accurate MMR measurement allows drilling personnel to make accurate judgments about drilling trends based on tool orientation characteristics. Therefore, this invention is of significant importance in improving drilling efficiency and reducing drilling costs in fields such as oil drilling. Attached Figure Description

[0015] Figure 1 This is a mechanical schematic diagram of the drilling speed measurement system in an embodiment of the present invention.

[0016] Figure 2 This is a schematic diagram of the measuring contact working in an embodiment of the present invention.

[0017] Figure 3 This is a schematic diagram of the process of the present invention.

[0018] Figure 4 The wellbore curves are obtained from measurements taken by the measuring contacts near the drill bit and those taken by the measuring contacts far from the drill bit.

[0019] Figure 5 The wellbore curves are obtained from measurements taken at the near-bit and far-bit measuring contacts.

[0020] Reference numerals: 1-External drill collar, 2-Measuring contact near drill bit, 3-Reset spring, 4-Magnetostrictive displacement sensor, 5-Signal transmission cable, 6-Main control module, 7-Measuring contact near drill bit, 8-Measuring contact far from drill bit, 9-Measuring contact far from drill bit, 10-Well wall. Detailed Implementation

[0021] The present invention will be described below with reference to the accompanying drawings.

[0022] See Figure 1The present invention discloses a mechanical drilling rate measurement system, comprising a mechanical drilling rate measurement body disposed inside a hollow outer drill collar 1, wherein the mechanical drilling rate measurement body is connected to a measuring contact via an elastic device, the measuring contact extending radially from the outer drill collar 1; the elastic device is a return spring 3, which allows the measuring contact to move closer to the mechanical drilling rate measurement body when pressed by an external force, and to move away from the mechanical drilling rate measurement body under the action of the return spring 3 if the external force is removed; The measuring contacts are configured in two groups: a near-bit measuring group and a far-bit measuring group, which are arranged along the axial direction of the outer drill collar 1. Both the near-bit measurement group and the far-bit measurement group include two measuring contacts. The two measuring contacts in both groups are symmetrically arranged and correspondingly positioned. The installation distance between the measuring contacts in the near-bit measurement group and their corresponding measuring contacts in the far-bit measurement group is... P They are known to be equal; The two measuring contacts in the near-bit measurement group are the near-bit upper measuring contact 2 and the near-bit lower measuring contact 7; the two measuring contacts in the far-bit measurement group are the far-bit upper measuring contact 8 and the far-bit lower measuring contact 9; the near-bit upper measuring contact 2 and the near-bit lower measuring contact 7 are symmetrically arranged at 180 degrees, and the near-bit upper measuring contact 2 and the far-bit upper measuring contact 8 are correspondingly arranged, and the near-bit lower measuring contact 7 and the far-bit lower measuring contact 9 are correspondingly arranged. The measuring contact extends naturally when no external force is applied, and the extension degree of the measuring contact is marked as 100%. The measuring contact is connected to the mechanical drilling speed measuring body via a return spring 3, allowing the measuring contact to freely extend and retract when subjected to external force or pressure from points, blocks, or surfaces protruding on the well wall 10. See [link / reference]. Figure 2 As shown.

[0023] The reset spring 3 can extend and retract under the action of external force, and drive the connected measuring contact to move.

[0024] Each measuring contact is equipped with a displacement measuring device at the position corresponding to the mechanical drilling speed measuring body, which is used to measure and collect displacement data of the measuring contact as it approaches or moves away from the mechanical drilling speed measuring body; The displacement measuring device is a magnetostrictive displacement sensor 4. During the drilling process, the outer surface of the measurement-while-drilling section rubs against the well wall 10. Due to the unevenness or irregularity of the well wall 10, the extension degree of the measuring contact is inconsistent. The displacement sensor can detect the extension and contraction displacement of the measuring contact. This type of sensor uses the magnetostrictive principle to accurately measure displacement by generating strain pulse signals through the intersection of two different magnetic fields. During the movement of the measuring contact, due to the magnetostrictive effect, the magnetostrictive displacement sensor 4 generates strain mechanical wave pulse signals, which can be converted to obtain the displacement of the measuring contact. Also includes: The main control module 6 is used to receive and calculate the data transmitted by the displacement measuring device. The main control module 6 includes an analog-to-digital conversion unit, a mechanical drilling rate calculation unit, and a communication unit. The analog-to-digital conversion unit collects the analog signal output by the magnetostrictive displacement sensor 4. The mechanical drilling rate calculation unit processes the collected data to calculate the mechanical drilling rate while drilling. The communication unit broadcasts the mechanical drilling rate results measured by the main control module 6 to other drilling tools, such as rotary steerable tools. These tools can adjust the drilling cycle and steerable parameters by judging the mechanical drilling rate, providing a mechanical drilling rate reference for intelligent downhole closed-loop automatic drilling.

[0025] The main control module 6 can be a TMS320F28335. The chip's internal AD can perform analog-to-digital conversion, and the TMS320F28335 itself can perform floating-point operations. Data transmission and communication can be carried out through the chip's SPI, SCI, IIC, CAN and other bus communication functions.

[0026] In practical use, the communication unit returns the drilling speed measurement data of the machine while drilling to the ground through traditional mud pulse communication. Ground personnel monitor the machine drilling speed measurement data and adjust the optimal guidance parameters in real time.

[0027] All displacement measuring devices are connected to the main control module 6 via signal transmission cables 5. For example, the magnetostrictive displacement sensor 4 measures the displacement of the measuring contact 2 near the drill bit due to the irregularity of the external well wall 10, and the resulting measurement signal is transmitted to the main control module 6 via the signal transmission cable 5 for processing. The main control module 6 is connected to the communication unit.

[0028] See Figure 2 A method for measuring and calculating the rate of drilling while drilling (MOD), and a MOD measurement system for performing the measurement and calculation, the method being as follows: A mechanical drilling rate measurement system is installed in the bottom drill string assembly, ensuring that the distance between the ends of the measuring contacts in the near-bit measurement group and the far-bit measurement group is greater than the drill bit diameter; the system and the magnetostrictive displacement sensor 4 are initialized. The drill bit drills at a certain drilling speed. The measuring contacts in both the near-bit measuring group and the far-bit measuring group extend out of the external drill collar 1 and contact the well wall 10. The extension degree of the measuring contacts is 0-100%, and its specific size is related to the height of the protrusions or depressions of the points, blocks, or surfaces of the well wall 10 that the present invention slides over. If a section of the well wall 10 is smooth without protrusions or depressions, the extension degree of the measuring contacts remains constant. If a section of the well wall 10 has protrusions or depressions, the extension degree of the measuring contacts changes with the protrusions and depressions of the well wall 10 when sliding over this section of the well wall 10.

[0029] The magnetostrictive displacement sensor 4 can record the uneven extension of the measuring contact due to friction between the measuring contact and the well wall 10 during the drilling process. The displacement sensor can measure the extension and retraction displacement of the measuring contact.

[0030] During the operation of the drill bit, the measuring contacts in the near-bit measuring group and the far-bit measuring group generate continuous displacements toward or away from the mechanical drilling speed measuring body according to the concavity and convexity rules of the well wall 10. The displacement measuring device continuously outputs an electrical signal of the measured contact displacement based on the continuous displacement generated by the measuring contact, and transmits it to the analog-to-digital conversion unit of the main control module 6. After signal sampling, it is input into the mechanical drilling speed calculation unit for mechanical drilling speed calculation. The drilling speed is obtained by using the ratio of the installation distance of the corresponding measuring contacts in the near-bit measurement group and the far-bit measurement group to the time it takes for the corresponding measuring contacts in the near-bit measurement group and the far-bit measurement group to pass through the same position on the well wall 10. The obtained mechanical drilling speed is transmitted to external equipment using a communication unit.

[0031] The specific process of calculating the mechanical drilling rate by the mechanical drilling rate calculation unit is as follows: The mechanical drilling rate calculation unit processes the two measuring contacts of the near-bit measurement group over a time period. T The displacement data recorded inside is used to draw a curve to obtain the profile curve of the well wall 10, which is the initial profile curve. The mechanical drilling rate calculation unit processes the two measuring contacts of the far-bit measurement group over a time period. T The displacement data recorded inside the well wall is used to draw a curve to obtain the profile curve of the well wall 10, which is the final profile curve. The initial and final profile curves are recorded and saved by the main control module 6, and the Euclidean distance method is used to compare the initial and final profile curves. Since the measurement while drilling mechanical drilling rate requires extremely high data processing real-time performance, the efficient improved Euclidean distance method is used to compare the profile curves of the wellbore 10.

[0032] Euclidean distance is an intuitive spatial distance metric used to calculate the straight-line distance between two points in multidimensional space. In curve similarity matching, if two curves are considered as a sequence of points, Euclidean distance measures overall similarity by comparing the positional differences of these points point by point.

[0033] The measuring contacts in the near-bit measurement group and the far-bit measurement group store the same number of data points, and the data stored by each measuring contact are normalized according to the following formula to eliminate differences in dimensions and amplitude. Calculate the Euclidean distance for each corresponding point on each curve; The borehole 10 curve data obtained from the two measuring contacts in the near-bit measurement group are set for each group to collect data. Each data point is saved to the main control module 6, and the time is recorded as follows: ; Based on the wellbore 10 curve data obtained from the two measuring contacts in the far-bit measurement group during the drilling process, each group is also set to collect data. There are 10 data points at this time. The data follows a first-in, first-out (FIFO) rule, meaning that sampling is complete. After the first data point, the newly sampled first... The next data point will become the latest data point, while the first data point will be overwritten, and so on. The Euclidean distance between corresponding measuring contacts in the near-bit and far-bit measurement groups was calculated, and the similarity was obtained. and ; The smaller the calculated Euclidean distance, the higher the similarity between the two curves. Curve similarity is calculated using the following formula. Conversion calculation; ; As the two measuring contacts in the far-end measuring group pass through the two measuring contacts in the near-end measuring group, data is collected. At 10 o'clock, this section of the well wall at each point... and At the same time, the similarity threshold of the curves above the well wall is greater than 10, and this moment is counted as... ; when and When the similarity threshold of the wellbore 10 curves is met, and it is known that... , The installation distance between the corresponding measuring contacts in the near and far drill bit measurement groups and the far drill bit measurement group is: Then, the mechanical drilling rate at this time is: .

[0034] The following examples illustrate this point: Assume that the data recorded at a certain point of the contact 2 near the drill bit is as follows: The data recorded at 8 points on the remote drill bit contact point are as follows: The data recorded at a certain point near the drill bit's lower contact point 7 is as follows: The data recorded at a certain point of the measuring contact 9 under the far-end drill bit is as follows: ; The distance between single point on the near drill bit measuring contact 2 and the far drill bit measuring contact 8 is: ; Total distance of 50 data points: ; Single-point distance between near-bit measuring contact 7 and far-bit measuring contact 9: ; Total distance of 50 data points: ; The wellbore 10 curve data obtained by the two measuring contacts in the near-bit measurement group are set to collect 50 data points in each group and saved to the main controller memory at 12:00:00. Based on the wellbore 10 curve data obtained by the two measuring contacts in the far-bit measurement group during the drilling process, each group is set to collect 50 data points. Unlike the near-bit measurement group data, the 50 data points follow the first-in-first-out rule. That is, after 50 data points are sampled, the newly sampled 51st data point will become the latest data point, while the first data point will be overwritten, and so on.

[0035] The smaller the calculated Euclidean distance, the higher the similarity between the two curves. The curve similarity conversion is calculated using the following formula: ; Therefore, the 50 data points collected by the measuring contact 8 at the far drill bit and the measuring contact 9 at the far drill bit will be continuously updated as the tool drills. The Euclidean distance between the measuring contact 2 at the near drill bit and the measuring contact 8 at the far drill bit will be calculated, and the similarity will be obtained. The similarity is 0.98; the Euclidean distance between the near-bit measuring contact 7 and the far-bit measuring contact 9 is calculated, and the similarity is obtained. It is 0.96.

[0036] like Figure 4 and Figure 5 The figure shows the wellbore curve 10 obtained by measuring the near-bit measuring contact 2 and the far-bit measuring contact 8, as well as the near-bit lower measuring contact 7 and the far-bit lower measuring contact 9.

[0037] When the far-bit measuring contact 8 and the far-bottom measuring contact 9 pass through the section of well wall 10 where 50 points were collected by the near-bit measuring contact 2 and the near-bottom measuring contact 7 respectively, the well wall 10 curves generated by instruments with similar characteristics passing through the same section of well wall 10 should be very similar. Therefore, and At this time, the similarity threshold of the curve 10 at the well wall is 0.95, and the recording time is 12:15:00.

[0038] when and When the similarity threshold of the wellbore 10 curves is met, and the known information is known. , If the installation distance between the corresponding measuring contacts in the near and far bit measurement groups and the far bit measurement group is 6 meters, then the mechanical drilling rate can be calculated at this time: ; The calculated real-time mechanical drilling rate in this embodiment is 24 m / h. After completing one wellbore 10 curve matching and mechanical drilling rate calculation, the initial profile curve data is cleared and reacquired. 10 data points are collected to await the next wellbore 10 curve matching and mechanical drilling rate calculation.

[0039] The present invention discloses a mechanical drilling speed measurement system for drilling, which is installed in the bottom drill string assembly. It can be located at any position in the bottom drill string assembly or near the drill bit, and there is no limitation on the specific installation position.

Claims

1. A mechanical drilling rate measurement system, comprising a mechanical drilling rate measurement body disposed inside a hollow external drill collar, characterized in that, The mechanical drilling speed measuring body is connected to a measuring contact via an elastic device, and the measuring contact extends radially from the outer drill collar. The measuring contacts are configured in two groups: a near-bit measuring group and a far-bit measuring group. Both the near-bit measurement group and the far-bit measurement group include two measuring contacts. The two measuring contacts in the near-bit measurement group and the far-bit measurement group are symmetrically arranged, and the two measuring contacts in the near-bit measurement group and the far-bit measurement group are correspondingly arranged. Each measuring contact is equipped with a displacement measuring device at the position corresponding to the mechanical drilling speed measuring body. This device measures and collects displacement data of the measuring contact as it approaches or moves away from the mechanical drilling speed measuring body.

2. The mechanical drilling rate measurement system as described in claim 1, characterized in that, The external drill collar is provided with the same number of protruding holes as the measuring contacts. A portion of the measuring contacts protrudes from the protruding holes and extends beyond the outer circumferential surface of the external drill collar, and the portion of the measuring contacts extending beyond the outer circumferential surface of the external drill collar is curved.

3. The mechanical drilling rate measurement system as described in claim 2, characterized in that, The elastic device is a return spring.

4. The mechanical drilling rate measurement system as described in claim 2, characterized in that, The displacement measuring device is a magnetostrictive displacement sensor.

5. A method for measuring and calculating the rate of drilling while drilling (MOD), comprising using a MOD measurement system as described in any one of claims 2-4, characterized in that, The method is as follows: A mechanical drilling rate measurement system is installed in the bottom drill string assembly while drilling, and the distance between the apex of the measuring contact in the near-bit measurement group and the far-bit measurement group is greater than the diameter of the drill bit. The drill bit drills at a certain drilling speed. The measuring contacts in both the near-bit and far-bit measuring groups extend out of the external drill collar and contact the well wall. During the operation of the drill bit, the measuring contacts in the near-bit measuring group and the far-bit measuring group will generate continuous displacements toward or away from the mechanical drilling speed measuring body according to the concavity and convexity of the well wall. The displacement measuring device continuously outputs the measured displacement of the measuring contact based on the continuous displacement generated by the measuring contact. The drilling speed is obtained by using the ratio of the installation distance of the corresponding measuring contacts in the near-bit and far-bit measuring groups to the time taken for the corresponding measuring contacts in the near-bit and far-bit measuring groups to pass through the same position on the wellbore.

6. The method for measuring and calculating mechanical drilling speed as described in claim 5, characterized in that, The specific process of calculating the mechanical drilling rate by the mechanical drilling rate calculation unit is as follows: The two measuring contacts of the near-bit measurement group during the time period T The displacement data recorded inside is used to draw a curve to obtain the contour curve of the well wall, which is the initial contour curve. The two measuring contacts of the far-drill bit measurement group during the time period T The displacement data recorded inside the well is used to draw a curve to obtain the well wall profile curve, which is the final profile curve. By recording and saving the initial and final contour curves, the Euclidean distance method is used to compare the initial and final contour curves. The measuring contacts in the near-bit measurement group and the far-bit measurement group store the same number of data points, and the data stored by each measuring contact are normalized to eliminate differences in dimensions and amplitude. Calculate the Euclidean distance D for each corresponding point on each curve; The wellbore curve data obtained from the two measuring contacts in the near-bit measurement group are set for each group to collect data. Each data point is saved, and this time is recorded as [time value]. ; Based on the wellbore curve data obtained from the two measuring contacts in the far-bit measurement group during the drilling process, each group is also set to collect data. There are 10 data points at this time. The data follows a first-in, first-out (FIFO) rule, meaning that sampling is complete. After the first data point, the newly sampled first... The next data point will become the latest data point, while the first data point will be overwritten, and so on. The Euclidean distance between corresponding measuring contacts in the near-bit and far-bit measurement groups was calculated, and the similarity was obtained. and ; The smaller the calculated Euclidean distance, the higher the similarity between the two curves. Curve similarity is calculated using the following formula. Conversion calculation; ； As the two measuring contacts in the far-end measuring group pass through the two measuring contacts in the near-end measuring group, data is collected. When this section of the well wall at each point, and At the same time, the similarity to the wellbore curve is greater than the threshold, and this moment is counted as... ; when and When the wellbore curve similarity threshold is met, and it is known that... , The installation distance between the corresponding measuring contacts in the near and far drill bit measurement groups and the far drill bit measurement group is: Then, the mechanical drilling rate at this time is: 。

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