Wellbore trajectory control methods, devices and electronic equipment

Abstract

This specification relates to the field of drilling technology, and more particularly to a wellbore trajectory control method, apparatus, and electronic equipment. The method includes: acquiring drilling engineering data during the drilling process, the drilling engineering data including inclination measurement data; calculating initial build-up rate data based on the acquired inclination measurement data; querying historical build-up rate data under the same drilling conditions as the initial build-up rate data; determining the actual build-up rate data based on the historical build-up rate data and the initial build-up rate data; determining the drilling deviation level based on the actual build-up rate data and the designed build-up rate data; and executing a corresponding wellbore trajectory control strategy based on the drilling deviation level. The embodiments of this specification can improve the wellbore trajectory control effect, reduce manual workload, and lower drilling risks.

Description

Technical Field

[0001] This specification relates to the field of drilling technology, and in particular to a wellbore trajectory control method, device, and electronic equipment. Background Technology

[0002] Oil and natural gas are important strategic materials and industrial resources. Increasing oil and gas production, especially the development of unconventional and complex oil and gas reservoirs, is of great significance to ensuring economic development and energy security. In recent years, with the large-scale development of unconventional and deep oil and gas reservoirs, the difficulty and risk of wellbore trajectory control have increased significantly. Existing technologies rely on manual methods for wellbore trajectory control.

[0003] However, manual wellbore trajectory control has drawbacks such as high workload, cumbersome process, and low efficiency. Furthermore, due to differences in the knowledge and experience of on-site engineers, the wellbore trajectory control results vary, leading to increased drilling risks. Summary of the Invention

[0004] This specification provides a wellbore trajectory control method, device, and electronic equipment to improve wellbore trajectory control performance, reduce manual workload, and lower drilling risks.

[0005] This specification provides an embodiment of a wellbore trajectory control method, including:

[0006] Collect drilling engineering data during the drilling process, including directional measurement data;

[0007] Calculate the initial slope rate based on the collected inclinometer data;

[0008] Query historical build-up rate data under the same drilling conditions as the initial build-up rate data;

[0009] The actual slope rate data is determined based on historical and initial slope rate data.

[0010] Determine the drilling deviation level based on the actual build-up rate data and the designed build-up rate data;

[0011] Based on the drilling deviation level, implement the corresponding wellbore trajectory control strategy.

[0012] This specification also provides a wellbore trajectory control device, comprising:

[0013] The acquisition unit is used to acquire drilling engineering data during the drilling process, including directional measurement data.

[0014] The calculation unit is used to calculate the initial slope rate data based on the collected inclinometer data;

[0015] The query unit is used to query historical build-up rate data that is under the same drilling conditions as the initial build-up rate data.

[0016] The first determining unit is used to determine the actual slope rate data based on historical slope rate data and initial slope rate data.

[0017] The second determining unit is used to determine the drilling deviation level based on the actual build-up rate data and the designed build-up rate data;

[0018] The execution unit is used to execute the corresponding wellbore trajectory control strategy according to the drilling deviation level.

[0019] This specification also provides an electronic device, including a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the computer program to implement the above-described wellbore trajectory control method.

[0020] The wellbore trajectory control method described in this specification can collect drilling engineering data during the drilling process, including directional survey data; calculate the initial build-up rate based on the collected directional survey data; query historical build-up rate data under the same drilling conditions as the initial build-up rate data; determine the actual build-up rate based on the historical and initial build-up rate data; determine the drilling deviation level based on the actual and designed build-up rate data; and execute a corresponding wellbore trajectory control strategy based on the drilling deviation level. By analyzing the drilling engineering data, the drilling deviation level can be obtained, and a corresponding wellbore trajectory control strategy can be executed for feedback correction. This achieves automated wellbore trajectory control, improving the efficiency and accuracy of wellbore trajectory control, reducing manual workload, and lowering drilling risks. Attached Figure Description

[0021] To more clearly illustrate the technical solutions in the embodiments or prior art of this specification, the drawings used in the description of the embodiments or prior art will be briefly introduced below. The drawings described below are only some embodiments recorded in this specification. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0022] Figure 1 This is a functional structure diagram of the drilling control device in the embodiments of this specification;

[0023] Figure 2 This is a flowchart illustrating the wellbore trajectory control method in the embodiments of this specification;

[0024] Figure 3 This is a functional structural diagram of the wellbore trajectory control device in the embodiments of this specification. Detailed Implementation

[0025] The technical solutions in the embodiments of this specification will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of this specification, and not all embodiments. The specific embodiments described herein are only used to explain this disclosure, and not to limit this disclosure. All other embodiments obtained by those skilled in the art based on the described embodiments of this disclosure are within the scope of protection of this disclosure. In addition, relational terms such as "first" and "second" are only used to distinguish one entity or operation from another entity or operation, and do not necessarily require or imply any such actual relationship or order between these entities or operations.

[0026] Oil and natural gas are vital strategic materials and industrial resources. Increasing oil and gas production, especially the development of unconventional and complex reservoirs, is crucial for ensuring economic development and energy security. Currently, automation and intelligent technologies are increasingly widely used in industrial manufacturing, ports, mines, aerospace, and other fields, driving a new round of industrial revolution. Exploring the use of automation and information technologies to reshape traditional drilling business models and promote continuous improvement in the quality, cost reduction, and efficiency of oil and gas exploration and development is of great significance.

[0027] In recent years, with the large-scale development of unconventional and deep oil and gas, the workload of horizontal wells has continued to increase by 7 times, and the length of the horizontal section has increased from about 800m to 1500-2000m and above. In addition, the complexity of geological and engineering conditions and the widespread application of high-end well trajectory control tools have greatly increased the difficulty and risk of well trajectory control.

[0028] In existing technologies, wellbore trajectory control operations follow the work team model. From a personnel perspective, to ensure the continuity of wellbore trajectory control operations, each work team requires at least four people (e.g., two directional drilling engineers and two instrument engineers), responsible for day and night shifts respectively. This model has drawbacks such as requiring a large number of engineers and high labor intensity. From the perspective of wellbore trajectory control methods and processes, during the operation, engineers continuously monitor drilling parameters, measurement while drilling (MWD) data, and the working status of downhole tools. This data is then compared and analyzed with the designed wellbore trajectory, past operational experience, and the operational status of adjacent wells. Simultaneously, based on wellbore trajectory deviations and geological steering commands, the wellbore trajectory design is adjusted, and the next control plan is planned based on the analysis and comparison. Wellbore trajectory adjustment control commands are issued in a timely manner to ensure the wellbore trajectory traverses the target formation. All of the above processes are done manually, which is labor-intensive and tedious. Especially under geological engineering conditions and the application of high-end tools such as rotary steering, the differences in the knowledge and experience of on-site engineers lead to significant differences in work performance. The number of on-site work trajectory adjustment instructions from different teams differs by nearly 10%, and the pure drilling time differs by nearly 10%. At the same time, the different abilities to judge downhole risks such as stuck drill pipe lead to an increase in complex risks.

[0029] Please see Figure 1 This specification provides an embodiment of a drilling control device.

[0030] The drilling control device may include a trajectory control execution system and a trajectory guidance system. The trajectory control execution system may include surface equipment, command transmission equipment, and downhole equipment. The surface equipment receives control commands from the trajectory guidance system and sends control commands to the command transmission equipment. The command transmission equipment receives control commands and sends control commands to the downhole equipment. The downhole equipment receives and executes the control commands. The surface equipment may include electronic equipment such as computers. The downhole equipment may include drilling tools, electrical control systems, etc.

[0031] The downhole equipment is also used to send drilling engineering data, such as measurement while drilling (MWD) data, during the directional drilling process to the surface equipment. The surface equipment is also used to receive and send the drilling engineering data to the trajectory guidance system. The trajectory guidance system is used to receive the drilling engineering data. The trajectory guidance system may include a data acquisition and processing module, a trajectory calculation module, a deviation evaluation module, an analysis and planning module, a control execution module, and a visualization monitoring and early warning module. Specifically, the data acquisition and processing module is used to generate a rotary directional drilling dataset based on the drilling engineering data. The trajectory calculation module is used to determine deviation data based on the data from the drilling process and the rotary directional drilling dataset. The deviation evaluation module is used to determine the drilling deviation level based on the deviation data. The analysis and planning module is used to replan the designed wellbore trajectory when the deviation is large. The control execution module is used to execute the corresponding wellbore trajectory control strategy according to the drilling deviation level, thereby generating corresponding control commands and sending control commands to the surface equipment. The visualization monitoring and early warning module is used to generate monitoring images and issue early warnings.

[0032] This specification provides a wellbore trajectory control method. The wellbore can be a trajectory formed by the interaction between the drill bit and the formation. The wellbore can include the wellbore of a horizontal well. The wellbore trajectory control method can be applied to electronic devices such as servers. For example, the wellbore trajectory control method can be applied to a trajectory guidance system.

[0033] Please see Figure 2 The wellbore trajectory control method may include the following steps.

[0034] Step 21: Collect drilling engineering data during the drilling process, including directional measurement data.

[0035] In some embodiments, drilling data during the directional drilling process can be collected in real time, or it can be collected periodically. For example, drilling data can be collected at set time intervals.

[0036] The aforementioned directional drilling is a drilling technology. This technology integrates a high-efficiency drill bit, directional power drill string, and MWD (Measurement While Drilling) system with computer software to form a directional drilling system. During drilling, it allows for timely changes between directional and rotary table operation modes, continuously performing directional build-up, inclination stabilization, inclination reduction, and azimuth adjustment operations without tripping the drill string and changing the drill string assembly. This technology enables the rapid drilling of high-quality wellbore trajectories.

[0037] In some embodiments, the drilling engineering data may include directional survey data. The directional survey data may include one or more of the following: inclination angle, azimuth angle, tool face angle, and depth data. The inclination angle represents the angle between the wellbore axis and the vertical line. The azimuth angle represents the angle between the projection of the wellbore axis onto the horizontal plane and the due north direction. The tool face angle represents the angle between the drill string axis and the wellbore axis. The depth data represents the wellbore depth at the time of drilling engineering data acquisition. The directional survey data may include dynamic directional survey data and / or static directional survey data. The dynamic directional survey data is measured while the drilling equipment is operating. The dynamic directional survey data includes inclination angle and tool face angle, etc. The static directional survey data is measured when the drilling equipment is not operating. The static directional survey data includes inclination angle and azimuth angle, etc.

[0038] In some embodiments, drilling engineering data during the directional drilling process can be acquired in real time via data transmission protocols such as TCP / IP and / or WITS. For example, drilling engineering data sent from surface equipment can be received via data transmission protocols such as TCP / IP and / or WITS. The drilling engineering data may include downhole measurement-while-drilling data, downhole tool data, control command data, logging data, etc. The downhole measurement-while-drilling data may include static directional measurement data, dynamic directional measurement data, gravitational acceleration values, magnetic field strength, etc. The downhole tool data may include downhole tool operating data and / or health status data. The operating data may include control mode, directional force magnitude, directional force direction, pulse intensity, battery voltage, etc. The health status data may include rotational speed, operating current, downhole vibration, etc. The control command data may include downlink time, command type, downlink parameters, downlink type, directional head control mode, target well inclination, etc. The logging data may include: wellbore depth, drill bit depth, mechanical drilling speed, hook load, rotational speed, standpipe pressure, mud flow rate, etc.

[0039] In some embodiments, after acquiring multiple drilling engineering data, the drilling operation status can be identified based on the multiple drilling engineering data. The drilling operation status may include drilling, circulation, reaming, tripping, etc.

[0040] Step 22: Calculate the initial inclination rate based on the collected inclination data.

[0041] In some embodiments, after acquiring multiple drilling data sets, the initial build-up rate can be calculated based on the directional measurement data within those multiple drilling data sets. The multiple drilling data sets may include multiple consecutive drilling data sets. In some scenario examples, the initial build-up rate can be calculated after acquiring a predetermined number of drilling data sets. For example, the predetermined number could be 10, 20, 50, etc. In other scenario examples, the initial build-up rate can be calculated after acquiring drilling data within a predetermined time period. For example, the predetermined time period could be 2 seconds, 3 seconds, 5 seconds, etc. In still other scenario examples, the initial build-up rate can also be calculated after acquiring drilling data within a predetermined depth range. For example, the predetermined depth range could include 0.5 meters, 1 meter, 2 meters, etc.

[0042] In some embodiments, wellbore inclination fitting can be performed on multiple inclination measurement data to obtain initial build-up rate data. The build-up rate data can be the total borehole curvature angle formed per unit drilling footage. The dimensions of the build-up rate data can include degrees / meter, degrees / 10 meters, degrees / 100 meters, etc. Wellbore inclination fitting can be performed directly on multiple inclination measurement data. Alternatively, outlier inclination measurement data can be filtered out from the multiple inclination measurement data; wellbore inclination fitting can be performed on the remaining inclination measurement data after filtering. The outlier inclination measurement data can be inclination measurement data that deviates significantly from other inclination measurement data among the multiple inclination measurement data. By filtering out outlier inclination measurement data, interference in the wellbore inclination fitting process can be eliminated, improving the accuracy of the initial build-up rate data. The wellbore inclination fitting can include linear fitting, and of course, it can also include curve fitting. This specification does not specifically limit this aspect in the embodiments.

[0043] Step 23: Query historical build-up rate data under the same drilling conditions as the initial build-up rate data.

[0044] In some embodiments, a drilling dataset may be provided. The drilling dataset may include at least one sub-dataset. Each sub-dataset may include drilling condition data and its corresponding historical build-up rate data. The drilling condition data may include one or more of the following basic wellbore data: designed wellbore trajectory, drilled wellbore trajectory, target area, wellbore structure, drill string assembly, directional commands, drilling parameters, formation type, etc. The drilling parameters may include bit pressure, rotational speed, displacement, etc. Of course, the drilling condition data may also include other data, such as control command data.

[0045] The following describes the process of constructing the drilling dataset.

[0046] It can acquire drilling engineering data in real time; it can obtain wellbore basic data; it can divide the acquired basic data and collected drilling engineering data into several subsets according to time period and / or depth segment; it can determine drilling condition data and historical build-up rate data within each subset; and it can incorporate these subsets into the drilling dataset. This allows the construction of a drilling dataset. The drilling dataset can be continuously enriched through accumulation. The drilling dataset is used for wellbore trajectory control.

[0047] The drilling engineering data includes downhole measurement-while-drilling data, downhole control tool data, control command data, and logging data. This drilling engineering data is real-time. The wellbore basic data includes the designed wellbore trajectory, the drilled wellbore trajectory, the target area, the wellbore structure, the drill string assembly, directional commands, and drilling parameters. This wellbore basic data is not real-time.

[0048] Real-time acquired drilling data can be divided into time-series data and depth-series data. The time-series data can include information on changes in well depth, drill bit position, standpipe pressure, drill weight, hook load, torque, rotational speed, and mechanical drilling speed over time. The depth-series data can include information on changes in standpipe pressure, drill weight, hook load, torque, rotational speed, and mechanical drilling speed over drilling depth. For ease of analysis, the time-series data can be processed at specific time intervals (e.g., 5-30 seconds) to obtain representative values ​​within that time interval. Similarly, the depth-series data can be processed at specific depth intervals (e.g., 0.1-5m) to obtain representative values ​​within that depth interval.

[0049] At set intervals, drilling data collected within a specific time period, along with corresponding wellbore baseline data, can be grouped into a subset of data. This can be done by directly including the drilling data collected within that time period and the corresponding wellbore baseline data. Alternatively, representative values ​​within that time period, along with corresponding wellbore baseline data, can be included in a subset of data. The set time period can include 1 minute, 2 minutes, 10 minutes, etc. Alternatively, at set intervals, depth segments can be defined, and data collected within those depth segments, along with corresponding wellbore baseline data, can be included in a subset of data. These depth segments can include 1 meter, 2 meters, 10 meters, etc. This results in several subsets of data.

[0050] Each subset can include multiple drilling engineering data and corresponding wellbore baseline data. Therefore, for each subset, build-up rate data can be calculated based on the directional measurement data from the multiple drilling engineering data within that subset, serving as the historical build-up rate data for that subset; one or more of the wellbore baseline data can be used as drilling condition data, or one or more of the wellbore baseline data and control command data can be used as drilling condition data.

[0051] The process of calculating historical slope rate data can be referred to the process of calculating initial slope rate data mentioned above, and will not be repeated here.

[0052] In some embodiments, drilling condition data corresponding to the drilling engineering data collected in step 21 can be obtained; a target subset can be obtained by matching the obtained drilling condition data in the drilling dataset; historical build-up rate data in the target subset can be obtained. The drilling condition data in the target subset matches the obtained drilling condition data. For example, the drilling condition data in the target subset is the same as the obtained drilling condition data. Another example is that the difference between the drilling condition data in the target subset and the obtained drilling condition data meets a set condition. Specifically, for example, the difference between the drilling condition data in the target subset and the obtained drilling condition data is less than or equal to a set threshold.

[0053] It should be noted that by matching within the drilling dataset, one or more target subsets can be obtained; and one or more historical pitching rate data can be obtained from the one or more target subsets.

[0054] It should also be noted that one or more of the following wellbore basic data can be obtained as drilling condition data: designed wellbore trajectory, drilled wellbore trajectory, target area, wellbore structure, drill string assembly, directional commands, drilling parameters, formation type, etc. Of course, control command data from the drilling engineering data can also be further obtained as drilling condition data.

[0055] Step 24: Determine the actual slope rate data based on historical slope rate data and initial slope rate data.

[0056] In some embodiments, the calculated initial build-up rate data may be inaccurate due to factors such as instrument performance, formation, and drilling section length. Therefore, historical build-up rate data can be used as a reference. The initial build-up rate data can be compared and evaluated with historical build-up rate data under the same drilling conditions to obtain the actual build-up rate data. Compared to the initial build-up rate data, the actual build-up rate data is more consistent with the actual situation because it takes into account historical build-up rate data under the same drilling conditions.

[0057] In some embodiments, the actual slope rate can be calculated based on historical slope rate data and initial slope rate data. For example, the average, median, etc., of the historical slope rate data and the initial slope rate data can be calculated as the actual slope rate data.

[0058] In some embodiments, step 23 can obtain historical slope rate data. The deviation between the historical slope rate data and the initial slope rate data can then be calculated. If the deviation is less than or equal to a set threshold, it indicates that the initial slope rate data is relatively accurate and can be used as the actual slope rate data. If the deviation is greater than the set threshold, it indicates that the accuracy of the initial slope rate data is poor, and the initial slope rate data can be corrected based on the historical slope rate data to obtain the actual slope rate data. The deviation can include the difference between the historical slope rate data and the initial slope rate data. Of course, other values ​​can also be used to represent the deviation, and this embodiment does not specifically limit this. The correction can include: calculating the average, median, etc., of the historical slope rate data and the initial slope rate data as the actual slope rate data. This allows the actual slope rate data to be determined based on the deviation between the historical slope rate data and the initial slope rate data. The actual slope rate data is determined by adhering as closely as possible to the initial slope rate data, thus making the actual slope rate data more consistent with the actual situation.

[0059] In some embodiments, step 23 can obtain multiple historical slope rate data. Then, the slope rate interval containing a preset proportion of historical slope rate data can be obtained; it can be determined whether the initial slope rate data is within the slope rate interval; if so, it indicates that the initial slope rate data is relatively accurate and can be determined as the actual slope rate data; if not, it indicates that the accuracy of the initial slope rate data is poor, and the initial slope rate data can be corrected according to the slope rate interval to obtain the actual slope rate data. The preset proportion may include 80%, 85%, 92%, etc.

[0060] The preset ratio can be used as the confidence level; the interval distribution of multiple historical slope rate data can be determined; the interval corresponding to the confidence level on the interval distribution can be obtained as the slope rate interval. In some scenario examples, the correction may include: determining representative slope rate data based on the slope rate interval, and determining actual slope rate data based on the representative slope rate data and the initial slope rate data. The representative slope rate data can be selected from within the slope rate interval. Alternatively, the representative slope rate data can also be calculated based on the slope rate interval. For example, the representative slope rate data may include the median of the slope rate interval, etc. Specifically, the average, median, etc. of the representative slope rate data and the initial slope rate data can be calculated as the actual slope rate data. Thus, the actual slope rate data can be a numerical value. In other scenario examples, the correction may include: generating a new slope rate interval based on the slope rate interval and the initial slope rate data as the actual slope rate data. Thus, the actual slope rate data can be a numerical range. For example, representative slope data can be determined based on the slope rate interval; the representative slope data and the initial slope data can be used as the upper and lower boundaries; the new slope rate interval can be determined based on the upper and lower boundaries.

[0061] Step 25: Determine the drilling deviation level based on the actual build-up rate data and the designed build-up rate data.

[0062] In some embodiments, build-up rate deviation data can be calculated based on actual build-up rate data and designed build-up rate data; the build-up rate deviation level can be determined based on the build-up rate deviation data, serving as the drilling deviation level. The level of the build-up rate deviation is positively correlated with the magnitude of the build-up rate deviation data. The designed build-up rate data can be the planned and designed build-up rate data. The actual build-up rate data can be a numerical value. The deviation can include the difference between the designed build-up rate data and the actual build-up rate data. Alternatively, the actual build-up rate data can also be a numerical range. The deviation can include the difference between the designed build-up rate data and the numerical range. For example, the difference between the designed build-up rate data and the upper and lower boundaries of the numerical range can be calculated separately, and the smaller of the two differences can be selected as the difference between the designed build-up rate data and the numerical range.

[0063] A set of slope deviation levels can be provided. This set may include at least one slope deviation level. Each slope deviation level may correspond to a slope deviation range. For example, the set may include a first slope deviation level, a second slope deviation level, a third slope deviation level, and a fourth slope deviation level. The first slope deviation level may correspond to a slope deviation range of 0-0.3° / 30m. The second slope deviation level may correspond to a slope deviation range of 0.3-0.5° / 30m. The third slope deviation level may correspond to a slope deviation range of 0.5-0.8° / 30m. The fourth slope deviation level may correspond to a slope deviation range >0.8° / 30m.

[0064] A build-up rate deviation level can be selected from the set of build-up rate deviation levels. Specifically, the build-up rate deviation data can be matched with the build-up rate deviation interval corresponding to each build-up rate deviation level to obtain the build-up rate deviation interval in which the build-up rate deviation data is located; the build-up rate deviation level corresponding to the build-up rate deviation interval can be obtained as the drilling deviation level.

[0065] In some embodiments, the future wellbore trajectory of a set length can be predicted based on actual build-up rate data; trajectory deviation data can be calculated based on the predicted wellbore trajectory and the designed wellbore trajectory; and the trajectory deviation level can be determined based on the trajectory deviation data, serving as the drilling deviation level. The set length can be 10m, 20m, 50m, etc. The level of trajectory deviation is positively correlated with the magnitude of the trajectory deviation data.

[0066] Based on actual build-up rate data, the existing wellbore trajectory can be extended to obtain a future wellbore trajectory of a predetermined length. The maximum distance between the predicted and designed wellbore trajectories can be calculated as trajectory deviation data.

[0067] A set of trajectory deviation levels can be provided. This set includes at least one trajectory deviation level. Each trajectory deviation level corresponds to a trajectory deviation range. For example, the set of trajectory deviation levels includes a first trajectory deviation level, a second trajectory deviation level, a third trajectory deviation level, and a fourth trajectory deviation level. The first trajectory deviation level may correspond to a trajectory deviation range of 0.1-0.3m. The second trajectory deviation level may correspond to a trajectory deviation range of 0.3-0.5m. The third trajectory deviation level may correspond to a trajectory deviation range of 0.5-0.8m. The fourth trajectory deviation level may correspond to a trajectory deviation range >0.8m.

[0068] Trajectory deviation levels can be selected from a set of trajectory deviation levels. Specifically, trajectory deviation data can be matched with the trajectory deviation intervals corresponding to each trajectory deviation level to obtain the trajectory deviation interval where the trajectory deviation data is located; the trajectory deviation level corresponding to this trajectory deviation interval can be obtained as the drilling deviation level.

[0069] In some embodiments, the build-up rate deviation level can be determined based on the build-up rate deviation data; the future wellbore trajectory of a set length can be predicted based on the actual build-up rate data; trajectory deviation data can be calculated based on the predicted wellbore trajectory and the designed wellbore trajectory; the trajectory deviation level can be determined based on the trajectory deviation data; and the drilling deviation level can be determined based on both the build-up rate deviation level and the trajectory deviation level. This comprehensive consideration of both build-up rate deviation and trajectory deviation allows for a more accurate determination of the drilling deviation level, thereby enabling more precise control of the wellbore trajectory and reducing deviations.

[0070] The process of determining the build-up rate deviation level and the trajectory deviation level can be referred to the aforementioned embodiments. It will not be repeated here. Furthermore, the level of drilling deviation is positively correlated with the magnitude of the actual deviation.

[0071] The minimum or maximum value between the build-up rate deviation level and the trajectory deviation level can be selected as the drilling deviation level.

[0072] Alternatively, the difference between the build-up rate deviation level and the trajectory deviation level can be determined. If the difference is less than or equal to a set threshold, the trajectory deviation level can be used as the drilling deviation level. If the difference is greater than or equal to the set threshold, the trajectory deviation level can be corrected based on the build-up rate deviation level to obtain the drilling deviation level. For example, a deviation level between the build-up rate deviation level and the trajectory deviation level can be selected as the drilling deviation level. Specifically, the selected deviation level can be any deviation level between the build-up rate deviation level and the trajectory deviation level. Of course, the deviation level can also be selected according to certain rules. This specification does not specifically limit this in the embodiments.

[0073] Step 26: Execute the corresponding wellbore trajectory control strategy according to the drilling deviation level.

[0074] In some embodiments, the drilling deviation levels determined in step 25 can be matched within a control strategy set to obtain a target wellbore trajectory control strategy; the target wellbore trajectory control strategy can then be executed. The control strategy set may include multiple wellbore trajectory control strategies. Each wellbore trajectory control strategy corresponds to a drilling deviation level. Specifically, the control strategy set may include a first wellbore trajectory control strategy, a second wellbore trajectory control strategy, and a third wellbore trajectory control strategy. The first, second, and third wellbore trajectory control strategies may each correspond to one or more drilling deviation levels. The drilling deviation level corresponding to the first wellbore trajectory control strategy is lower than the drilling deviation level corresponding to the second wellbore trajectory control strategy. The drilling deviation level corresponding to the second wellbore trajectory control strategy is lower than the drilling deviation level corresponding to the third wellbore trajectory control strategy.

[0075] The drilling deviation level corresponding to the first wellbore trajectory control strategy is very small. The first wellbore trajectory control strategy is used to maintain the current control command unchanged, thus preserving the status quo. Therefore, executing the first wellbore trajectory control strategy will not produce any action.

[0076] The second wellbore trajectory control strategy corresponds to a slightly larger drilling deviation level. This strategy adjusts drilling parameters to ensure the future wellbore trajectory closely matches the designed trajectory. Executing this strategy generates a prompt message, which can be sent to the surface equipment. This prompt message instructs personnel to adjust drilling parameters. Personnel can input control commands on the surface equipment based on the prompt message. The surface equipment receives these commands and sends them to the downhole equipment. These commands instruct the downhole equipment to adjust drilling parameters. Alternatively, executing the second wellbore trajectory control strategy can directly generate control commands, which can be sent to the surface equipment. The surface equipment receives and sends these commands to the downhole equipment, instructing it to adjust drilling parameters. This achieves automatic wellbore trajectory control.

[0077] The third wellbore trajectory control strategy corresponds to a relatively large drilling deviation level. Adjusting drilling parameters alone cannot bring the future wellbore trajectory closer to the designed trajectory. Therefore, executing the third wellbore trajectory control strategy can generate alarm information, which can be sent to the surface equipment. This alarm information prompts the operators to redesign the wellbore trajectory. For example, the wellbore trajectory can be redesigned based on the current location and target area. The operators can input the redesigned wellbore trajectory into the surface equipment. The surface equipment can receive and send the redesigned wellbore trajectory to the trajectory guidance system. Additionally, the operators can input new control commands into the surface equipment. The surface equipment can receive and send these new control commands to the downhole equipment. The new control commands are executed to ensure that the downhole equipment follows the redesigned wellbore trajectory during drilling.

[0078] The wellbore trajectory control method described in this specification can collect drilling engineering data during the drilling process, including directional survey data; calculate the initial build-up rate based on the collected directional survey data; query historical build-up rate data under the same drilling conditions as the initial build-up rate data; determine the actual build-up rate based on the historical and initial build-up rate data; determine the drilling deviation level based on the actual and designed build-up rate data; and execute a corresponding wellbore trajectory control strategy based on the drilling deviation level. By analyzing the drilling engineering data, the drilling deviation level can be obtained, and a corresponding wellbore trajectory control strategy can be executed for feedback correction. This achieves automated wellbore trajectory control, improving the efficiency and accuracy of wellbore trajectory control, reducing manual workload, and lowering drilling risks.

[0079] The wellbore trajectory control method described in this specification can collect drilling engineering data such as measurement while drilling and wellbore trajectory in real time during directional drilling, automatically analyze, plan, and decide on the optimal drilling route, and automatically control the directional drilling tool to achieve closed-loop drilling. This technology achieves geological engineering goals automatically, reliably, and with high quality, with the highest efficiency and minimal manual labor.

[0080] Please see Figure 3 This specification also provides a wellbore trajectory control device, comprising:

[0081] The acquisition unit 31 is used to acquire drilling engineering data during the drilling process, including directional measurement data.

[0082] The calculation unit 32 is used to calculate the initial slope rate data based on the collected inclination data;

[0083] Query unit 33 is used to query historical build-up rate data under the same drilling conditions as the initial build-up rate data;

[0084] The first determining unit 34 is used to determine the actual slope rate data based on historical slope rate data and initial slope rate data;

[0085] The second determining unit 35 is used to determine the drilling deviation level based on the actual build-up rate data and the designed build-up rate data;

[0086] The execution unit 36 ​​is used to execute the corresponding wellbore trajectory control strategy according to the drilling deviation level.

[0087] This specification also provides an electronic device, including a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the computer program to implement the above-described wellbore trajectory control method.

[0088] This specification also provides a computer-readable storage medium storing a computer program that, when executed by a processor, implements the above-described wellbore trajectory control method.

[0089] This specification also provides a computer program product, which includes a computer program that, when executed by a processor, implements the above-described wellbore trajectory control method.

[0090] Those skilled in the art will understand that this specification can be provided as a method, system, or computer program product. Therefore, this specification may take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware. Furthermore, this specification may take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0091] This specification is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments thereof. It should be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. The computer may be a personal computer, laptop computer, cellular phone, camera phone, smartphone, personal digital assistant, media player, navigation device, email device, game console, tablet computer, wearable device, or any combination of these devices.

[0092] The functional units in the embodiments of this specification can be integrated into one processing unit, or each functional unit can exist physically separately, or two or more functional units can be integrated into one processing unit.

[0093] Those skilled in the art will understand that the descriptions of the various embodiments in this specification have different focuses, and parts not described in detail in a certain embodiment can be referred to in the relevant descriptions of other embodiments. Furthermore, it is understood that those skilled in the art, after reading this specification, can conceive of any combination of some or all of the embodiments listed in this specification without creative effort, and such combinations are also within the scope of disclosure and protection of this specification.

[0094] Although this specification has been described through embodiments, those skilled in the art will understand that the above embodiments are merely illustrative of the core ideas of this specification. Those skilled in the art will appreciate that many variations and modifications are possible with this specification. It is intended that the appended claims encompass these variations and modifications without departing from the spirit of this specification.

Claims

1. A wellbore trajectory control method, characterized in that, include: Collect drilling engineering data during the drilling process, including directional measurement data; Calculate the initial slope rate based on the collected inclinometer data; Query historical build-up rate data under the same drilling conditions as the initial build-up rate data; The actual slope rate data is determined based on historical and initial slope rate data. Determine the drilling deviation level based on the actual build-up rate data and the designed build-up rate data; Based on the drilling deviation level, implement the corresponding wellbore trajectory control strategy.

2. The method according to claim 1, characterized in that, The number of drilling engineering data is multiple; The steps involved in calculating the initial slope rate data include: The initial build-up rate data were obtained by fitting multiple well inclination data.

3. The method according to claim 1, characterized in that, The steps involved in querying historical slope rate data include: Obtain the drilling condition data corresponding to the drilling engineering data; Based on drilling condition data, a target subset is obtained by matching within the drilling dataset; the drilling dataset includes at least one subset, and each subset includes drilling condition data and its corresponding historical build-up rate data. Obtain historical slope rate data from the target subset.

4. The method according to claim 1, characterized in that, The method further includes: Real-time acquisition of downhole measurement while drilling data, downhole control tool data, control command data, and logging data; Obtain basic data from the wellbore; The acquired basic data and the real-time collected data are divided into several subsets according to time period and / or depth segment; Within each subset of data sets, drilling condition data and historical build-up rate data are determined. The aforementioned subsets of data are included in the drilling dataset.

5. The method according to claim 1, characterized in that, The number of historical slope rate data is multiple; The steps involved in determining the actual slope rate data include: Obtain the slope range where the historical slope rate data of the preset ratio is located; Determine whether the initial slope rate data is within the slope rate interval; If so, the initial slope rate data shall be determined as the actual slope rate data; If not, the initial slope rate data is corrected according to the slope rate range to obtain the actual slope rate data.

6. The method according to claim 1, characterized in that, The distinctions in determining drilling deviation levels include: Calculate the deviation data of the climbing rate based on the actual climbing rate data and the designed climbing rate data; Determine the level of slope deviation based on the slope deviation data; Based on the actual build-up rate data, predict the well trajectory for the future set length; Based on the predicted wellbore trajectory and the designed wellbore trajectory, calculate the trajectory deviation data; Determine the trajectory deviation level based on the trajectory deviation data; The drilling deviation level is determined based on the build-up rate deviation level and the trajectory deviation level.

7. The method according to claim 1, characterized in that, The steps involved in implementing a wellbore trajectory control strategy include: The drilling deviation level is matched with the control strategy set to obtain the target wellbore trajectory control strategy. The control strategy set includes multiple wellbore trajectory control strategies, and each wellbore trajectory control strategy corresponds to a drilling deviation level. Implement the target wellbore trajectory control strategy.

8. The method according to claim 7, characterized in that, The control strategy set includes a first wellbore trajectory control strategy, a second wellbore trajectory control strategy, and a third wellbore trajectory control strategy; the first wellbore trajectory control strategy is used to indicate keeping the control command unchanged; the second wellbore trajectory control strategy is used to indicate adjusting the drilling parameters to correct the actual wellbore trajectory; and the third wellbore trajectory control strategy is used to indicate replanning the designed wellbore trajectory.

9. A wellbore trajectory control device, characterized in that, include: The acquisition unit is used to acquire drilling engineering data during the drilling process, including directional measurement data. The calculation unit is used to calculate the initial slope rate data based on the collected inclinometer data; The query unit is used to query historical build-up rate data that is under the same drilling conditions as the initial build-up rate data. The first determining unit is used to determine the actual slope rate data based on historical slope rate data and initial slope rate data. The second determining unit is used to determine the drilling deviation level based on the actual build-up rate data and the designed build-up rate data; The execution unit is used to execute the corresponding wellbore trajectory control strategy according to the drilling deviation level.

10. An electronic device, characterized in that, include: processor; Memory used to store processor-executable instructions; The processor executes the instructions to implement the method as described in any one of claims 1-8.

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