Real-time identification system and method for downhole drilling conditions and related equipment

Abstract

The present invention discloses a system, method, and related equipment for real-time identification of downhole drill bit operating conditions. The system comprises: a downhole vibration measurement sub, a measurement sub data collector, a data transmission device, an MWD logging-while-drilling instrument, and a computing device; the downhole vibration measurement sub, data collector, data transmission device, and computing device are sequentially connected; the logging-while-drilling instrument is used to collect mud logging parameter data and transmit the logging parameter data to the computing device; the vibration measurement sub is used to measure the three-axis vibration parameters of the drill bit downhole; the measurement sub data collector is used to collect the three-axis vibration parameters collected by the vibration measurement sub and transmit them to the computing device; the computing device determines the real-time operating condition of the drill bit based on the logging parameters collected by the logging-while-drilling instrument and the three-axis vibration parameters of the drill bit downhole. The present invention can achieve real-time and accurate identification of the drill bit operating condition, avoiding complex downhole drill bit operating conditions such as excessive drill bit wear and mud balling.

Description

Technical Field

[0001] The present invention relates to the technical field of oilfield drilling engineering, and in particular to a real-time identification system and method for downhole working conditions of a drill bit, and related equipment. Background Art

[0002] During oil and gas exploration, it is discovered that more and more proven oil and gas resources are buried in deep formations. Deep and ultra-deep wells have become a trend in oil and gas development, and PDC drill bits have become the most widely used drill bits in deep well drilling. However, when using drill bits in deep and ultra-deep wells, due to the deep burial of oil and gas reservoirs, the working status of PDC drill bits in the wellbore is affected by various factors and difficult to identify. Frequent tripping and drilling limits the drilling efficiency of deep and ultra-deep wells, and increases the development cost of deep reservoirs.

[0003] To reduce drilling costs and improve reservoir development efficiency, drillers typically replace the cutters on worn drill bits after removal, repairing and reusing them, significantly reducing drill bit costs. However, this approach relies on timely and accurate decision-making for removal. Removing the drill bit too early limits the drill bit's footage, increasing the cost per trip, while removing it too late wears out the drill bit, rendering it useless for reuse. Summary of the Invention

[0004] The inventors of this invention have discovered that, currently, most drilling operators tend to determine the downhole operating conditions of PDC drill bits based on their own experience. However, this method is significantly influenced by the operator's subjective factors and experience level. A small number of operators also use mud logging parameters as a criterion for identifying the downhole operating conditions of PDC drill bits. However, this method has a single set of identification parameters and poor accuracy, which cannot meet on-site requirements. There is an urgent need for a systematic method that can accurately predict the downhole operating conditions of PDC drill bits in real time, improve the scientificity and accuracy of drilling decision-making, and further enhance the effectiveness of PDC drill bits in deep and ultra-deep well development.

[0005] In view of the above problems, the present invention is proposed to provide a real-time identification system and method for downhole working conditions of a drill bit and related equipment that overcome the above problems or at least partially solve the above problems.

[0006] In a first aspect, an embodiment of the present invention provides a real-time identification system for downhole working conditions of a drill bit, comprising: a downhole vibration measurement sub, a downhole vibration measurement sub data collector, a data transmission device, an MWD logging while drilling tool, and a computing device; wherein:

[0007] The downhole vibration measurement sub, the downhole vibration measurement sub data collector, the data transmission device and the computing device are connected in sequence;

[0008] The MWD logging while drilling instrument is used to collect downhole logging parameter data and transmit the logging parameter data to the computing device on the ground;

[0009] The vibration measurement sub is used to measure the three-axis vibration parameters of the drill bit downhole;

[0010] The downhole vibration measurement sub data collector is used to collect the triaxial vibration parameters collected by the vibration measurement sub and transmit them to the computing device through the data transmission device;

[0011] The computing device determines the real-time working condition information of the drill bit through the logging parameter data collected by the MWD logging while drilling instrument and the three-axis vibration parameters of the drill bit downhole collected by the downhole vibration measurement pup data collector.

[0012] Furthermore, the above-mentioned drill bit downhole working condition real-time identification system also includes:

[0013] The client device is used to connect to the computing device and display the real-time working status of the drill bit.

[0014] Furthermore, the measuring sub data collector includes: at least three triaxial acceleration sensors and a circuit for supplying power and transmitting signals to the triaxial acceleration sensors; wherein:

[0015] At least two triaxial acceleration sensors are arranged longitudinally on the inner side wall of the downhole vibration measurement sub, and at least one triaxial acceleration sensor is arranged transversely on the bottom of the inner wall of the vibration measurement sub.

[0016] Furthermore, the operating range of the three-axis acceleration sensor is ±200g and the accuracy is 80mg.

[0017] Furthermore, the data transmission device is an MWD pulse transmitter.

[0018] Furthermore, the real-time identification system for downhole working conditions of a drill bit further includes: a data connection device;

[0019] The data connection device is connected to the data transmission device and the computing device respectively, and is used to process the triaxial vibration parameters transmitted by the data transmission device and the logging parameter data collected by the MWD logging while drilling instrument respectively, and transmit the processed data to the computing device.

[0020] Furthermore, the data connection device is used to eliminate abnormal drilling process data from the logging parameter data; and to process the three-axis vibration parameters according to axial vibration parameters, tangential vibration parameters and radial vibration parameters respectively, and periodically send the processed data to the computing device according to a preset time interval.

[0021] Furthermore, the computing device is specifically used to periodically obtain the three-axis vibration parameters collected by the downhole vibration measurement short section data collector and the logging parameters collected by the downhole MWD logging instrument; and determine the cutting depth value, rock breaking energy ratio, and friction coefficient based on the logging parameters, and calculate the change ratio of the cutting depth value, rock breaking energy ratio, and friction coefficient between the current measurement cycle and the previous measurement cycle; and calculate the change ratio of the axial vibration parameter, tangential vibration parameter, and radial vibration parameter in the three-axis vibration parameters between the current measurement cycle and the previous measurement cycle; determine the real-time working condition information of the drill bit based on the calculated change ratio of the cutting depth value, rock breaking energy ratio, and friction coefficient between the current measurement cycle and the previous measurement cycle, as well as the change ratio of the axial vibration parameter, tangential vibration parameter, and radial vibration parameter between the current measurement cycle and the previous measurement cycle.

[0022] In a second aspect, an embodiment of the present invention provides a method for identifying downhole working conditions of a drill bit, applicable to a computing device, comprising:

[0023] Periodically obtain the triaxial vibration parameters collected by the downhole vibration measurement sub data collector and the logging parameters collected by the downhole MWD logging while drilling instrument;

[0024] Determine the cutting depth value, rock-breaking specific energy, and friction coefficient based on the logging parameters, and calculate the change ratio of the cutting depth value, rock-breaking specific energy, and friction coefficient between the current measurement cycle and the previous measurement cycle; and calculate the change ratio of the axial vibration parameter, tangential vibration parameter, and radial vibration parameter in the three-axis vibration parameters between the current measurement cycle and the previous measurement cycle;

[0025] The real-time working condition information of the drill bit is determined based on the calculated cutting depth value, rock-breaking specific energy, and the ratio of change of the friction coefficient between the current measurement cycle and the previous measurement cycle, as well as the ratio of change of the axial vibration parameter, tangential vibration parameter, and radial vibration parameter between the current measurement cycle and the previous measurement cycle.

[0026] Furthermore, based on the logging parameters, the cutting depth value, rock breaking specific energy, and friction coefficient are determined, and the change ratio of the cutting depth value, rock breaking specific energy, and friction coefficient between the current measurement cycle and the previous measurement cycle is calculated, including:

[0027] Calculate the depth of cut DOC per measuring cycle:

[0028]

[0029] In formula 1: DOC represents the cutting depth of the drill bit; ROP is the mechanical drilling speed; n is the rotational speed;

[0030] Calculate the difference ΔDOC between the cutting depth of the current measurement cycle and the cutting depth of the previous measurement cycle; As the ratio of change between the current measurement period and the previous measurement period;

[0031] Calculate the rock breaking specific energy M in each measurement cycle SE :

[0032]

[0033] In formula 2: M SE is the mechanical specific energy; WOB is the weight on bit; T is the torque; ROP is the mechanical penetration rate; d B is the drill bit diameter;

[0034] Calculate the difference ΔM between the cutting depth of the current measurement cycle and the rock breaking specific energy in the previous measurement cycle SE ;calculate As the ratio of change between the current measurement period and the previous measurement period;

[0035] Calculate the drill bit friction coefficient μ during each measurement cycle:

[0036]

[0037] In formula 3: WOB is weight on bit; T is torque; d B is the drill bit diameter;

[0038] Calculate the difference Δμ between the cutting depth of the current measurement cycle and the rock breaking specific energy in the previous measurement cycle; As the ratio of change between the current measurement period and the previous measurement period.

[0039] Furthermore, when:

[0040] μ≤0.3; axial vibration acceleration, tangential vibration acceleration and radial vibration acceleration all show a decreasing trend, and It is determined that the drill bit is in a preset severe wear state.

[0041] Furthermore, when:

[0042] μ≤0.5; the axial vibration acceleration, tangential vibration acceleration and radial vibration acceleration in each measurement cycle show a trend of increasing first and then decreasing, and when the trend is decreasing , it is determined that the drill bit is in a preset normal wear state.

[0043] Furthermore, when:

[0044] It shows a decreasing trend, and μ≤0.3; the lithologic profile is shale or water-sensitive formation; the axial vibration acceleration, tangential vibration acceleration, and radial vibration acceleration all show a decreasing trend within each measurement cycle, with the tangential vibration acceleration decreasing the most. When g(y)>g(x), increase the drill bit displacement to 110% to 120% of the original displacement;

[0045] Determine whether the μ increases, DOC increases, and M SE If not, it is determined that the drill bit is in a mud balling state.

[0046] Further, if it is determined that the μ does not increase, DOC does not increase, and M SE If the drill is lowered, continue drilling.

[0047] In a third aspect, an embodiment of the present invention provides a device for identifying downhole working conditions of a drill bit, comprising:

[0048] The parameter acquisition module is used to periodically acquire the triaxial vibration parameters collected by the downhole vibration measurement sub data collector and the logging parameters collected by the downhole MWD logging while drilling instrument;

[0049] A ratio calculation module is used to determine the cutting depth value, rock breaking specific energy, and friction coefficient based on the logging parameters, and calculate the change ratio of the cutting depth value, rock breaking specific energy, and friction coefficient between the current measurement cycle and the previous measurement cycle; and calculate the change ratio of the axial vibration parameter, tangential vibration parameter, and radial vibration parameter in the three-axis vibration parameters between the current measurement cycle and the previous measurement cycle;

[0050] The working condition identification module is used to determine the real-time working condition information of the drill bit based on the calculated cutting depth value, rock-breaking specific energy, and the change ratio of the friction coefficient between the current measurement cycle and the previous measurement cycle, as well as the change ratio of the axial vibration parameter, tangential vibration parameter, and radial vibration parameter between the current measurement cycle and the previous measurement cycle.

[0051] In a fourth aspect, an embodiment of the present invention provides a computing device; wherein, the memory stores a computer program, and when the program is executed by the processor, it can implement the method for identifying the downhole working condition of the drill bit as described above.

[0052] In a fifth aspect, an embodiment of the present invention provides a computer program product, which includes a computer program, and when the computer program is executed by a processor, it implements the method for identifying the downhole working condition of a drill bit as described in any one of claims 1 to 9.

[0053] In a sixth aspect, an embodiment of the present invention provides a non-temporary computer-readable storage medium, which, when the instructions in the storage medium are executed by a processor of a system chip, enables the processor to execute the method for identifying the downhole working condition of a drill bit as described above.

[0054] The beneficial effects of the above technical solutions provided by the embodiments of the present invention include at least:

[0055] The real-time identification system, method, and related equipment for the drill bit's downhole operating condition provided by the embodiments of the present invention collect the drill bit's three-axis vibration parameters and logging parameter data in real time, and identify the drill bit's real-time operating condition based on the real-time collected three-axis vibration parameters and logging parameter data. Compared with the traditional method of judging the drill bit's downhole operating condition through experience or only through the change pattern of logging parameters, the system greatly improves the accuracy of identification, which is crucial for making timely decisions to start drilling. In addition, due to its real-time calculation characteristics, it can be displayed to construction personnel in real time, providing reference suggestions for decision makers and avoiding complex downhole drill bit conditions such as excessive drill bit wear and mud balls. Due to the wide range of its calculation parameters, it is applicable to most drill bit types and formation properties. The real-time identification system and method for the drill bit's downhole operating condition have a wide range of applicability.

[0056] Other features and advantages of the present invention will be described in the following description, and in part will become apparent from the description, or will be understood by practicing the present invention. The purposes and other advantages of the present invention can be realized and obtained by the structures particularly pointed out in the written description, claims, and drawings.

[0057] The technical solution of the present invention is further described in detail below through the accompanying drawings and embodiments. BRIEF DESCRIPTION OF THE DRAWINGS

[0058] The accompanying drawings are used to provide a further understanding of the present invention and constitute a part of the specification. Together with the embodiments of the present invention, they are used to explain the present invention and do not constitute a limitation of the present invention. In the accompanying drawings:

[0059] Figure 1 Schematic diagram of the architecture of a real-time identification system for downhole working conditions of a drill bit according to an embodiment of the present invention;

[0060] Figure 2 Schematic diagram of the structure of a PDC drill bit in an embodiment of the present invention;

[0061] Figure 3 This is a flow chart of a method for identifying downhole working conditions of a drill bit according to an embodiment of the present invention;

[0062] Figure 4 This is a flow chart for identifying the working status of a PDC drill bit by using changes in parameters such as cutting depth, rock breaking specific energy, and friction coefficient change ratio in an embodiment of the present invention;

[0063] Figure 5 4 is a block diagram of a device for identifying downhole working conditions of a drill bit according to an embodiment of the present invention. DETAILED DESCRIPTION

[0064] Exemplary embodiments of the present disclosure will be described in more detail below with reference to the accompanying drawings. Although exemplary embodiments of the present disclosure are shown in the accompanying drawings, it should be understood that the present disclosure can be implemented in various forms and should not be limited by the embodiments set forth herein. Rather, these embodiments are provided to enable a more thorough understanding of the present disclosure and to fully convey the scope of the present disclosure to those skilled in the art.

[0065] The embodiment of the present invention provides a real-time identification system for downhole working conditions of a drill bit, referring to Figure 1 and Figure 2 As shown, it includes: a downhole vibration measurement sub 1, a downhole vibration measurement sub data collector 2, a data transmission device 3, an MWD logging while drilling tool 4 and a computing device 5; wherein:

[0066] The downhole vibration measurement sub 1, the downhole vibration measurement sub data collector 2, the data transmission device 3 and the computing device 5 are connected in sequence;

[0067] An MWD logging while drilling instrument 4 is used to collect downhole logging parameter data and transmit the logging parameter data to a computing device 5 on the surface;

[0068] Downhole vibration measurement sub 1, used to measure the three-axis vibration parameters of the drill bit downhole;

[0069] A downhole vibration measurement sub data collector 2 is used to collect the triaxial vibration parameters collected by the vibration measurement sub 1 and transmit them to the computing device 5 via the data transmission device 3;

[0070] The computing device 5 determines the real-time working condition information of the drill bit through the logging parameter data collected by the MWD logging while drilling instrument 4 and the three-axis vibration parameters of the drill bit collected by the downhole vibration measurement sub data collector 2.

[0071] The computing device 5 mentioned above can be, for example, any intelligent device with computing capabilities in the prior art, such as various processors, computers, etc.

[0072] Reference Figure 1 As shown, the real-time identification system for downhole drill bit working conditions also includes:

[0073] The client device 6 is used to connect to the computing device to display the real-time working status of the drill bit to provide reference suggestions for drilling construction.

[0074] Preferably, the data transmission device 3 may be, for example, an MWD pulse transmitter 7 .

[0075] By using the MWD pulse transmitter 7, the data collected underground can be transmitted to the surface through wireless pulse MWD without relying on data cables, so that the complex working conditions underground have less impact on data transmission.

[0076] Reference Figure 1 As shown, the real-time identification system for downhole working conditions of a drill bit further includes: a data connection device 8;

[0077] The data connection device 8 is connected to the data transmission device 3 and the computing device 5 respectively, and is used to process the triaxial vibration parameters transmitted by the data transmission device 3 and the logging parameter data collected by the MWD logging while drilling instrument respectively, and transmit the processed data to the computing device 5.

[0078] The MWD logging-while-drilling instrument collects data such as drilling pressure, torque, well depth, mechanical penetration rate, rotational speed, drilling fluid density, pump pressure, displacement, wellbore structure, and formation lithology. The data collected by the MWD logging-while-drilling instrument is transmitted via drilling fluid pressure pulses, converting the measured parameters into drilling fluid pressure pulses that are then transmitted to the surface as the drilling fluid circulates. The surface signal receiving device of the MWD logging-while-drilling instrument is connected to a data interface 8, which then transmits the data to a computing device 5. The data collection and transmission process of the MWD logging-while-drilling instrument is conventional and will not be described in detail here.

[0079] Furthermore, the data connection device 8 is configured to remove abnormal drilling process data from the logging parameter data; and to process the triaxial vibration parameters separately according to axial vibration parameters, tangential vibration parameters, and radial vibration parameters, and periodically transmit the processed data to the computing device at preset time intervals. For example, the data connection device transmits data at a frequency of 10 seconds.

[0080] The data connection device 8 can automatically suspend data transmission according to changes in drilling pressure and torque, making it easier for the operator to observe the construction status of the entire drilling process.

[0081] Furthermore, the above-mentioned computing device 5 is used to obtain the three-axis vibration parameters collected by the downhole vibration measurement pup data collector and the logging parameters collected by the downhole MWD logging while drilling instrument; and according to the logging parameters, respectively determine the cutting depth value, rock-breaking specific energy, and friction coefficient, and calculate the change ratio of the cutting depth value, rock-breaking specific energy, and friction coefficient between the current measurement cycle and the previous measurement cycle; and calculate the change ratio of the axial vibration parameter, tangential vibration parameter, and radial vibration parameter in the three-axis vibration parameters between the current measurement cycle and the previous measurement cycle; according to the determined change ratio of the cutting depth value, rock-breaking specific energy, and friction coefficient between the current measurement cycle and the previous measurement cycle, and the change ratio of the axial vibration parameter, tangential vibration parameter, and radial vibration parameter between the current measurement cycle and the previous measurement cycle, determine the real-time working condition information of the drill bit.

[0082] Reference Figure 2 As shown in the structural diagram of the PDC drill bit, the downhole vibration measurement sub 1 is installed above the PDC drill bit 9 and below the MWD logging while drilling instrument 4. The position layout close to the PDC drill bit 9 ensures that the downhole vibration measurement sub 1 can accurately collect drill bit vibration parameters in real time during drilling.

[0083] The downhole vibration measurement sub 1 contains at least three triaxial acceleration sensors 11, two of which are longitudinally arranged on the inner wall of the downhole vibration measurement sub, and one triaxial acceleration sensor is arranged transversely on the bottom of the inner wall of the vibration measurement sub;

[0084] The measuring sub data collector includes at least three triaxial acceleration sensors and a circuit for supplying power and transmitting signals to the triaxial acceleration sensors;

[0085] Preferably, the three-axis acceleration sensor has an operating range of ±200g and an accuracy of 80mg.

[0086] The triaxial acceleration sensor 11 is connected to the downhole vibration sub data collector 2 to transmit the triaxial vibration parameters of the drill bit in real time;

[0087] The downhole vibration sub data collector 2 is connected to the MWD pulse transmitter 7, and the collected drill bit triaxial vibration data is transmitted to the surface in real time through the MWD pulse transmitter 7.

[0088] Based on the above-mentioned real-time identification system for downhole working condition of a drill bit, an embodiment of the present invention provides a method for identifying downhole working condition of a drill bit, which is applicable to a computing device, referring to Figure 3 As shown, the process of the method includes:

[0089] S31, periodically acquiring triaxial vibration parameters collected by a downhole vibration measurement sub data collector and logging parameters collected by a downhole MWD logging while drilling instrument;

[0090] S32. Determine the cutting depth value, rock-breaking specific energy, and friction coefficient based on the logging parameters, and calculate the change ratio of the cutting depth value, rock-breaking specific energy, and friction coefficient between the current measurement cycle and the previous measurement cycle; and calculate the change ratio of the axial vibration parameter, the tangential vibration parameter, and the radial vibration parameter, among the three-axis vibration parameters, between the current measurement cycle and the previous measurement cycle;

[0091] S33. Determine the real-time operating condition information of the drill bit based on the calculated cutting depth value, rock-breaking specific energy, and the ratio of change of the friction coefficient between the current measurement cycle and the previous measurement cycle, as well as the ratio of change of the axial vibration parameter, tangential vibration parameter, and radial vibration parameter between the current measurement cycle and the previous measurement cycle.

[0092] In each measurement cycle, the cutting depth (DOC), rock breaking energy (M SE ) and the friction coefficient (μ) are calculated by the following steps:

[0093] 1) Cutting depth is a parameter that measures the depth of the formation cut by the drill bit per revolution. Its calculation method is:

[0094]

[0095] In formula 1: DOC represents the cutting depth of the drill bit; ROP is the mechanical drilling speed; n is the rotational speed;

[0096] Accordingly, the method for calculating the change ratio of the cutting depth value between the current measurement cycle and the previous measurement cycle is as follows: calculate the difference ΔDOC between the cutting depth of the current measurement cycle and the cutting depth of the previous measurement cycle; calculate As the ratio of change between the current measurement period and the previous measurement period;

[0097] 2) Rock breaking specific energy (M SE ) represents the mechanical specific energy required to crush a unit volume of rock. Usually, when the drill bit is severely worn or packed with mud, the rock-breaking specific energy will increase significantly because its cutting teeth cannot effectively bite into the crushed rock. Its calculation method is:

[0098]

[0099] In formula 2: M SE is the mechanical specific energy; WOB is the weight on bit; T is the torque; ROP is the mechanical penetration rate; d B is the drill bit diameter;

[0100] Accordingly, the method for calculating the change ratio of the rock breaking energy in the current measurement cycle and the previous measurement cycle is as follows: Calculate the difference ΔM between the cutting depth in the current measurement cycle and the rock breaking energy in the previous measurement cycle SE ;calculate As the ratio of change between the current measurement period and the previous measurement period;

[0101] 3) The drill bit friction coefficient (μ) represents the relationship between bit pressure and torque. Generally, as bit pressure increases, torque also increases. However, the torque increases at different levels of wear. The more severe the drill bit wear, the smaller the torque increase. The friction coefficient μ is calculated as follows:

[0102]

[0103] In formula 3: WOB is weight on bit; T is torque; d B is the drill bit diameter;

[0104] Calculate the difference Δμ between the cutting depth of the current measurement cycle and the rock breaking specific energy in the previous measurement cycle; As the ratio of change between the current measurement period and the previous measurement period.

[0105] The calculation equipment calculates the axial vibration parameters, tangential vibration parameters, and radial vibration parameters. The vibration parameters are determined based on the amplitude of the vibration acceleration change. Generally, when the drill bit is severely worn, the vibration amplitude will be significantly reduced. In other words, the change ratio is relatively large.

[0106] Reference Figure 4 The flowchart shown in the figure shows how the calculation device calculates the rock breaking energy (M) by cutting depth (DOC) and rock breaking energy (M SE ), the friction coefficient (μ) change ratio and other parameters can be used to identify the working status of the PDC drill bit in real time.

[0107] Reference Figure 4 As shown, when the following conditions are met: μ≤0.3; axial vibration acceleration, tangential vibration acceleration and radial vibration acceleration all show a decreasing trend, and , it is determined that the drill bit is in a preset severe wear state.

[0108] In the prior art, drill bit wear levels are divided into levels 1-8. During actual drilling, if the wear level exceeds level 3, drilling will become difficult. Therefore, in the embodiment of the present invention, the wear level of the above-mentioned severe wear state is level 3-8 (excluding level 3).

[0109] When the following conditions are met: μ≤0.5; the axial vibration acceleration, tangential vibration acceleration and radial vibration acceleration in each measurement cycle show a trend of increasing first and then decreasing, and when the trend is decreasing It is determined that the drill bit is in a preset normal wear state.

[0110] In the embodiment of the present invention, the normal wear state refers to a wear level of 1-3 (including level 3).

[0111] When the following conditions are met: It shows a decreasing trend, and μ≤0.3; the lithologic profile is shale or water-sensitive formation; the axial vibration acceleration, tangential vibration acceleration, and radial vibration acceleration all show a decreasing trend within each measurement cycle, with the tangential vibration acceleration decreasing the most. When g(y)>g(x), increase the drill bit displacement to 110% to 120% of the original displacement;

[0112] Determine whether μ increases, DOC increases, and M SE If the downward movement does not occur, it is judged that the drill bit is in a mud balling state.

[0113] Bit balling refers to the formation of mud on the drill bit surface, which can occur during both drilling and tripping. Bit balling reduces the penetration of the PDC drill teeth into the formation, resulting in reduced penetration and a slower drilling speed. In severe cases, the balling can block the drill bit and the water hole, causing increased pump pressure and even loss of drilling speed. If it occurs during tripping, it can cause annular blockage.

[0114] If it is judged that there is no increase in μ, DOC and M SE If the drilling speed drops, the drill bit continues to drill and continues the steps of periodically collecting and calculating the triaxial vibration parameters and logging parameter data.

[0115] Based on the same inventive concept, an embodiment of the present invention also provides a device for identifying the downhole working condition of a drill bit. Since the principles of the problems solved by these devices are similar to the aforementioned method for identifying the downhole working condition of a drill bit, the implementation of the device can refer to the implementation of the aforementioned method, and the repeated parts will not be repeated.

[0116] An embodiment of the present invention provides a device for identifying downhole working conditions of a drill bit, referring to Figure 5 As shown, including:

[0117] The parameter acquisition module 51 is used to periodically acquire the triaxial vibration parameters collected by the downhole vibration measurement sub data collector and the logging parameters collected by the downhole MWD logging while drilling instrument;

[0118] The ratio calculation module 52 is used to determine the cutting depth value, rock breaking specific energy, and friction coefficient based on the logging parameters, and calculate the change ratio of the cutting depth value, rock breaking specific energy, and friction coefficient between the current measurement cycle and the previous measurement cycle; and calculate the change ratio of the axial vibration parameter, tangential vibration parameter, and radial vibration parameter in the three-axis vibration parameters between the current measurement cycle and the previous measurement cycle;

[0119] The working condition identification module 53 is used to determine the real-time working condition information of the drill bit based on the calculated cutting depth value, rock breaking specific energy, and the change ratio of the friction coefficient between the current measurement cycle and the previous measurement cycle, as well as the change ratio of the axial vibration parameter, tangential vibration parameter, and radial vibration parameter between the current measurement cycle and the previous measurement cycle.

[0120] An embodiment of the present invention further provides a computing device; wherein the memory stores a computer program, and when the program is executed by the processor, it can implement the aforementioned method for identifying the downhole working condition of the drill bit.

[0121] An embodiment of the present invention further provides a computer program product, which includes a computer program. When the computer program is executed by a processor, it implements the aforementioned method for identifying downhole working conditions of a drill bit.

[0122] An embodiment of the present invention further provides a non-transitory computer-readable storage medium. When the instructions in the storage medium are executed by a processor of a system chip, the processor is enabled to execute the aforementioned method for identifying downhole working conditions of a drill bit.

[0123] Regarding the device for identifying the downhole working condition of a drill bit in the above embodiment, the specific manner in which each module performs operations has been described in detail in the embodiment of the method and will not be elaborated on here.

[0124] The real-time identification system, method, and related equipment for the drill bit's downhole working condition provided by the embodiments of the present invention collect the drill bit's three-axis vibration parameters and logging parameter data in real time, and identify the drill bit's real-time working condition based on the real-time collected three-axis vibration parameters and logging parameter data. Compared with the traditional method of judging the drill bit's downhole working condition through experience or only through the change pattern of logging parameters, the system greatly improves the recognition accuracy, which is crucial for making timely decisions to start drilling. In addition, due to its real-time calculation characteristics, it is convenient to display it to construction personnel in real time, providing reference suggestions for decision makers and avoiding complex downhole drill bit conditions such as excessive drill bit wear and mud balls. Due to the wide range of its calculation parameters, it is applicable to most drill bit types and formation properties. The real-time identification system and method for the drill bit's downhole working condition have a wide range of applicability.

[0125] Those skilled in the art will appreciate that embodiments of the present invention may be provided as methods, systems, or computer program products. Thus, the present invention may take the form of an entirely hardware embodiment, an entirely software embodiment, or an embodiment combining software and hardware. Furthermore, the present invention may take the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to magnetic disk storage and optical storage, etc.) containing computer-usable program code.

[0126] The present invention is described with reference to flowcharts and / or block diagrams of methods, devices (systems), and computer program products according to embodiments of the present invention. It should be understood that each process and / or block in the flowcharts and / or block diagrams, as well as combinations of processes and / or blocks in the flowcharts and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, a special-purpose computer, an embedded processor, or other programmable data processing device to produce a machine, so that the instructions executed by the processor of the computer or other programmable data processing device generate instructions for implementing the processes in the flowcharts and / or block diagrams. Figure 1 a process or multiple processes and / or boxes Figure 1 A device that provides the functions specified in a block or multiple blocks.

[0127] These computer program instructions may also be stored in a computer readable memory that can direct a computer or other programmable data processing device to work in a specific manner, so that the instructions stored in the computer readable memory produce an article of manufacture comprising an instruction device, which implements the process Figure 1 a process or multiple processes and / or boxes Figure 1 The function specified in one or more boxes.

[0128] These computer program instructions can also be loaded onto a computer or other programmable data processing device so that a series of operational steps are executed on the computer or other programmable device to produce a computer-implemented process, thereby providing the instructions executed on the computer or other programmable device for implementing the process. Figure 1 a process or multiple processes and / or boxes Figure 1 A step that specifies a function in one or more boxes.

[0129] Obviously, those skilled in the art may make various changes and modifications to the present invention without departing from the spirit and scope of the present invention. Thus, if such changes and modifications fall within the scope of the claims and their equivalents, the present invention is intended to include such changes and modifications.

Claims

1. A method for identifying downhole working conditions of a drill bit, characterized in that: include: Periodically obtain the triaxial vibration parameters collected by the downhole vibration measurement sub data collector and the logging parameters collected by the downhole MWD logging while drilling instrument; According to the logging parameters, the cutting depth DOC and rock breaking specific energy M are determined. SE , friction coefficient μ, calculate the change ratio of the cutting depth value between the current measurement cycle and the previous measurement cycle The ΔDOC is the difference between the cutting depth of the current measurement cycle and the cutting depth of the previous measurement cycle; Calculate the change ratio of rock breaking energy between the current measurement period and the previous measurement period The ΔM SE The difference between the rock-breaking energy in the current measurement period and the rock-breaking energy in the previous measurement period; Calculate the change ratio of the friction coefficient between the current measurement cycle and the previous measurement cycle The Δμ is the difference between the friction coefficient of the current measurement cycle and the friction coefficient of the previous measurement cycle; and calculating the change ratio of the axial vibration parameter, the tangential vibration parameter and the radial vibration parameter in the three-axis vibration parameters between the current measurement cycle and the previous measurement cycle; Determine the real-time working condition information of the drill bit based on the calculated cutting depth value, rock breaking specific energy, and friction coefficient change ratio between the current measurement cycle and the previous measurement cycle, as well as the change ratio between the current measurement cycle and the previous measurement cycle of the axial vibration parameter, tangential vibration parameter, and radial vibration parameter; When satisfied: μ≤0.3; axial vibration acceleration g(x), tangential vibration acceleration g(y) and radial vibration acceleration g(z) all show a decreasing trend, and It is determined that the drill bit is in a preset severe wear state; When satisfied: μ≤0.5; the axial vibration acceleration, tangential vibration acceleration and radial vibration acceleration in each measurement cycle show a trend of increasing first and then decreasing, and when the trend is decreasing It is determined that the drill bit is in a preset normal wear state; When satisfied: It shows a decreasing trend, and μ≤0.3; the lithologic profile is shale or water-sensitive formation; the axial vibration acceleration, tangential vibration acceleration, and radial vibration acceleration all show a decreasing trend within each measurement cycle, with the tangential vibration acceleration decreasing the most. When g(y)>g(x), increase the drill bit displacement to 110% to 120% of the original displacement; Determine whether the μ increases, DOC increases, and M SE If not, it is determined that the drill bit is in a mud balling state; If it is judged that the above-mentioned μ increase, DOC increase and M SE If the drill is lowered, continue drilling.

2. The method according to claim 1, wherein The depth of cut DOC within each measuring cycle is determined according to the following formula: In formula 1: ROP is the mechanical drilling speed; n is the rotational speed; The rock breaking specific energy M in each measurement cycle SE Determined according to the following formula: In formula 2: WOB is weight on bit; T is torque; ROP is mechanical drilling speed; d B is the drill bit diameter; The drill bit friction coefficient μ in each measuring cycle is determined according to the following formula: In formula 3: WOB is weight on bit; T is torque; d B is the drill bit diameter.

3. A real-time identification system for executing the method for identifying downhole working conditions of a drill bit according to claim 1 or 2, characterized in that: include: Downhole vibration measurement sub, downhole vibration measurement sub data collector, data transmission device, MWD logging while drilling tool and computing equipment; including: The downhole vibration measurement sub, the downhole vibration measurement sub data collector, the data transmission device and the computing device are connected in sequence; The MWD logging while drilling instrument is used to collect downhole logging parameter data and transmit the logging parameter data to the computing device on the ground; The vibration measurement sub is used to measure the three-axis vibration parameters of the drill bit downhole; The downhole vibration measurement sub data collector is used to collect the triaxial vibration parameters collected by the vibration measurement sub and transmit them to the computing device through the data transmission device; The computing device determines the real-time working condition information of the drill bit through the logging parameter data collected by the MWD logging while drilling instrument and the three-axis vibration parameters of the drill bit downhole collected by the downhole vibration measurement pup data collector.

4. The system according to claim 3, wherein: Also includes: The client device is used to connect to the computing device and display the real-time working status of the drill bit.

5. The system according to claim 3, wherein: The measuring sub data collector includes: at least three triaxial acceleration sensors and a circuit for supplying power and transmitting signals to the triaxial acceleration sensors; wherein: At least two triaxial acceleration sensors are arranged longitudinally on the inner side wall of the downhole vibration measurement sub, and at least one triaxial acceleration sensor is arranged transversely on the bottom of the inner wall of the vibration measurement sub.

6. The system according to claim 5, wherein: The three-axis acceleration sensor has an operating range of ±200g and an accuracy of 80mg.

7. The system according to claim 5, wherein: The data transmission device is an MWD pulse transmitter.

8. The system according to any one of claims 3 to 7, wherein: Also includes: Data connection device; The data connection device is connected to the data transmission device and the computing device respectively, and is used to process the triaxial vibration parameters transmitted by the data transmission device and the logging parameter data collected by the MWD logging while drilling instrument respectively, and transmit the processed data to the computing device.

9. The system according to claim 8, wherein The data connection device is used to eliminate abnormal drilling process data from the logging parameter data; and is used to process the three-axis vibration parameters according to axial vibration parameters, tangential vibration parameters and radial vibration parameters respectively, and periodically send the processed data to the computing device according to a preset time interval.

10. The system according to claim 3, wherein: The computing device is specifically used to periodically acquire the three-axis vibration parameters collected by the downhole vibration measurement sub data collector and the logging parameters collected by the downhole MWD logging while drilling instrument; and determine the cutting depth value, rock-breaking specific energy, and friction coefficient based on the logging parameters, and calculate the change ratio of the cutting depth value, rock-breaking specific energy, and friction coefficient between the current measurement cycle and the previous measurement cycle; and calculate the change ratio of the axial vibration parameter, tangential vibration parameter, and radial vibration parameter in the three-axis vibration parameters between the current measurement cycle and the previous measurement cycle; and determine the real-time working condition information of the drill bit based on the calculated change ratio of the cutting depth value, rock-breaking specific energy, and friction coefficient between the current measurement cycle and the previous measurement cycle, as well as the change ratio of the axial vibration parameter, tangential vibration parameter, and radial vibration parameter between the current measurement cycle and the previous measurement cycle.

11. A device for executing the method for identifying downhole working conditions of a drill bit according to claim 1 or 2, characterized in that: include: The parameter acquisition module is used to periodically acquire the triaxial vibration parameters collected by the downhole vibration measurement sub data collector and the logging parameters collected by the downhole MWD logging while drilling instrument; A ratio calculation module is used to determine the cutting depth value, rock breaking specific energy, and friction coefficient based on the logging parameters, and calculate the change ratio of the cutting depth value, rock breaking specific energy, and friction coefficient between the current measurement cycle and the previous measurement cycle; and calculate the change ratio of the axial vibration parameter, tangential vibration parameter, and radial vibration parameter in the three-axis vibration parameters between the current measurement cycle and the previous measurement cycle; The working condition identification module is used to determine the real-time working condition information of the drill bit based on the calculated cutting depth value, rock-breaking specific energy, and the change ratio of the friction coefficient between the current measurement cycle and the previous measurement cycle, as well as the change ratio of the axial vibration parameter, tangential vibration parameter, and radial vibration parameter between the current measurement cycle and the previous measurement cycle.

12. A computing device; wherein: The memory stores a computer program, which, when executed by the processor, can implement the method for identifying the downhole working condition of a drill bit as claimed in claim 1 or 2.

13. A computer program product, characterized in that The computer program product comprises a computer program, and when the computer program is executed by a processor, the method for identifying downhole working conditions of a drill bit according to claim 1 or 2 is implemented.

14. A non-transitory computer-readable storage medium, characterized in that When the instructions in the storage medium are executed by a processor of a system chip, the processor is enabled to execute the method for identifying downhole working conditions of a drill bit as claimed in claim 1 or 2.

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