Well track control method and device and electronic equipment

Abstract

The invention relates to the technical field of well drilling, in particular to a well track control method and device and electronic equipment. The method comprises the steps that drilling engineering data in the drilling process are collected, and the drilling engineering data comprise inclinometry data; calculating initial build-up rate data according to the collected inclinometry data; querying historical build-up rate data under the same drilling condition as the initial build-up rate data; determining actual build-up rate data according to the historical build-up rate data and the initial build-up rate data; according to the actual build-up rate data and the designed build-up rate data, the drilling deviation level is determined; and executing a corresponding well track control strategy according to the drilling deviation level. According to the embodiment of the invention, the well track control effect can be improved, the manual workload is reduced, and the drilling risk is reduced.

Description

Technical Field

[0001] The present invention relates to the field of drilling technology, and in particular to a wellbore trajectory control method, device and electronic equipment. Background Art

[0002] Oil and natural gas are important strategic materials and industrial resources. Increasing oil and gas production, especially realizing 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, the difficulty and risk of wellbore trajectory control have increased significantly. In existing technologies, manual methods are used to control wellbore trajectory.

[0003] However, the manual method of wellbore trajectory control has the disadvantages of heavy workload, cumbersome process and low efficiency. In addition, due to the differences in knowledge and experience of field engineers, the wellbore trajectory control effects vary, resulting in increased drilling risks. Summary of the invention

[0004] The embodiments of the present specification provide a wellbore trajectory control method, device and electronic equipment for improving the wellbore trajectory control effect, reducing manual workload and lowering drilling risks.

[0005] The embodiment of this specification provides a wellbore trajectory control method, comprising:

[0006] Collecting drilling engineering data during the drilling process, wherein the drilling engineering data includes inclination survey data;

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

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

[0009] Determine the actual build-up rate data based on the historical build-up rate data and the initial build-up rate data;

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

[0011] According to the drilling deviation level, the corresponding wellbore trajectory control strategy is executed.

[0012] The embodiment of this specification also provides a wellbore trajectory control device, including:

[0013] A collection unit, used for collecting drilling engineering data during the drilling process, wherein the drilling engineering data includes inclination measurement data;

[0014] A calculation unit, used for calculating initial slope rate data according to the collected inclination measurement data;

[0015] A query unit, used to query historical build-up rate data under the same drilling conditions as the initial build-up rate data;

[0016] A first determination unit is used to determine actual build rate data according to historical build rate data and initial build rate data;

[0017] A second determination unit is used to determine the drilling deviation level according to 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] The embodiment of the present 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 implements the wellbore trajectory control method when executing the computer program.

[0020] The borehole trajectory control method of the embodiment of this specification can collect drilling engineering data during the drilling process, and the drilling engineering data includes inclination data; the initial inclination rate data can be calculated based on the collected inclination data; the historical inclination rate data under the same drilling conditions as the initial inclination rate data can be queried; the actual inclination rate data can be determined based on the historical inclination rate data and the initial inclination rate data; the drilling deviation level can be determined based on the actual inclination rate data and the designed inclination rate data; and the corresponding borehole trajectory control strategy can be executed based on the drilling deviation level. In this way, the drilling deviation level can be obtained by analyzing the drilling engineering data, and the corresponding borehole trajectory control strategy can be executed for feedback correction. Thereby, automated borehole trajectory control is realized, which can improve the efficiency and accuracy of borehole trajectory control, reduce manual workload, and reduce drilling risks. BRIEF DESCRIPTION OF THE DRAWINGS

[0021] In order to more clearly illustrate the embodiments of this specification or the technical solutions in the prior art, the drawings required for use in the embodiments or the description of the prior art will be briefly introduced below. The drawings described below are only some embodiments recorded in this specification. For ordinary technicians in this field, other drawings can be obtained based on these drawings without paying creative labor.

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

[0023] Figure 2 It is a flowchart of the wellbore trajectory control method in the embodiment of this specification;

[0024] Figure 3 It is a functional structure diagram of the wellbore trajectory control device in the embodiment of this specification. DETAILED DESCRIPTION

[0025] The technical solutions in the embodiments of this specification will be clearly and completely described below in conjunction with the drawings in the embodiments of this specification. Obviously, the described embodiments are only part of the embodiments of this specification, rather than all of the embodiments. The specific embodiments described herein are only used to explain the present disclosure, rather than to limit the present disclosure. Based on the described embodiments of the present disclosure, all other embodiments obtained by those of ordinary skill in the art are within the scope of protection of the present 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 important strategic materials and industrial resources. Increasing oil and gas production, especially the development of complex oil and gas reservoirs such as unconventional ones, is of great significance to ensuring economic development and energy security. Currently, automation and intelligent technologies are increasingly used in industrial manufacturing, ports, mines, aerospace and other fields, promoting a new round of industrial revolution. It is of great significance to explore the use of automation and information technology to reshape the traditional drilling business model and promote the continuous improvement of quality, cost reduction and efficiency of oil and gas exploration and development.

[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 complex geological and engineering conditions and the widespread application of high-end wellbore trajectory control tools have greatly increased the difficulty and risk of wellbore trajectory control.

[0028] In the existing technology, the wellbore trajectory control operation mode follows the operation team model. From the perspective of personnel composition structure, in order to ensure the continuity of the wellbore trajectory control operation, each of the operation teams needs to be equipped with at least 4 people (for example, 2 directional well engineers and 2 instrument engineers), who are responsible for day and night shift operations respectively. This model has the disadvantages of 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 information (MWD, Measure While Drilling)), downhole tool working status and other data, and then compare and analyze with the designed wellbore trajectory, previous operation experience and neighboring well operations. At the same time, according to the wellbore trajectory deviation and geological guidance instructions, the wellbore trajectory design is adjusted and the next control plan is planned according to the analysis and comparison, and the wellbore trajectory adjustment control instructions are issued in a timely manner to ensure that the wellbore trajectory passes through the target formation. The above processes are all completed manually, which is labor-intensive and cumbersome. Especially under geological engineering conditions and the application of high-end tools such as rotary steering, the differences in knowledge and experience of field engineers lead to obvious differences in operation performance. The number of on-site operation trajectory adjustment instructions of different teams differs by nearly 1 times, and the pure drilling time differs by nearly 10%. At the same time, the different abilities to judge underground risks such as stuck drill lead to increased complex risks.

[0029] See also Figure 1 The embodiments of this specification provide 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 ground equipment, instruction transmission equipment and downhole equipment. The ground equipment is used to receive control instructions from the trajectory guidance system and send control instructions to the instruction transmission equipment. The instruction transmission equipment is used to receive control instructions and send control instructions to the downhole equipment. The downhole equipment is used to receive control instructions and execute the control instructions. Among them, the ground 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 during the steerable 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 visual monitoring and early warning module. Among them, the data acquisition and processing module is used to generate a rotary steerable drilling data set based on the drilling engineering data. The trajectory calculation module is used to determine the deviation data based on the data in the drilling process and the rotary steerable drilling data set. 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 re-plan 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 the corresponding control instruction and sending the control instruction to the surface equipment. The visual monitoring and early warning module is used to generate monitoring images and issue early warnings.

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

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

[0034] Step 21: Collect drilling engineering data during the drilling process, wherein the drilling engineering data includes inclination measurement data.

[0035] In some embodiments, the drilling engineering data during the steerable drilling process may be collected in real time, or may be collected periodically, for example, at set time intervals.

[0036] The directional drilling is a drilling technology. This drilling technology is formed by using a high-performance drill bit, a directional power drilling tool and an MWD (measurement while drilling device) as a whole, and supplemented by computer software to form a directional drilling system. During the drilling process, the two working conditions of directional and rotary table can be changed in time to continuously complete directional deflection, increase deflection, stabilize deflection, reduce deflection and twist azimuth operations without starting the drill and changing the drilling tool assembly. This technology can quickly drill a high-quality wellbore trajectory.

[0037] In some embodiments, the drilling engineering data may include inclination data. The inclination data may include one or more of inclination angle, azimuth, tool face angle, and depth data. The inclination angle is used to indicate the angle between the borehole axis and the vertical line. The azimuth is used to indicate the angle between the projection of the borehole axis on the horizontal plane and the true north direction. The tool face angle is used to indicate the angle between the drilling tool axis and the borehole axis. The depth data is used to indicate the depth of the borehole when collecting drilling engineering data. The inclination data may include dynamic inclination data and / or static inclination data. The dynamic inclination data is measured when the drilling equipment is running. The dynamic inclination data includes inclination angle and tool face angle, etc. The static inclination data is measured when the drilling equipment is not running. The static inclination data includes inclination angle and azimuth, etc.

[0038] In some embodiments, the drilling engineering data in the process of directional drilling can be collected in real time through data transmission protocols such as TCP / IP and / or WITS. For example, the drilling engineering data sent by the ground equipment can be received through 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 instruction data, logging data, etc. The downhole measurement while drilling data may include static inclination data, dynamic inclination data, gravity acceleration value, magnetic field strength, etc. The downhole tool data may include working data and / or health status data of the downhole tool. The working data may include control mode, guide force size, guide force direction, pulse strength, battery voltage, etc. The health status data may include speed, working current, downhole vibration, etc. The control instruction data may include downlink time, instruction type, downlink parameter, downlink type, guide head control mode, target well deviation, etc. The logging data may include: wellbore depth, drill bit depth, mechanical penetration rate, hook load, rotation speed, riser pressure, mud flow, etc.

[0039] In some embodiments, after a plurality of drilling engineering data are collected, the drilling working status may be identified according to the plurality of drilling engineering data. The drilling working status may include drilling, circulation, reaming, tripping, etc.

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

[0041] In some embodiments, after each acquisition of multiple drilling engineering data, initial inclination rate data can be calculated based on the inclination data in the multiple drilling engineering data. The multiple drilling engineering data may include multiple continuous drilling engineering data. In some scenario examples, initial inclination rate data can be calculated after each acquisition of a set number of drilling engineering data. For example, the set number may be 10, 20, 50, etc. In other scenario examples, initial inclination rate data can be calculated after each acquisition of drilling engineering data of a set time period. For example, the set time period may be 2 seconds, 3 seconds, 5 seconds, etc. In other scenario examples, initial inclination rate data can also be calculated after each acquisition of drilling engineering data within a set depth segment. For example, the set depth segment may include 0.5 meters, 1 meter, 2 meters, etc.

[0042] In some embodiments, well inclination fitting can be performed on multiple inclination measurement data to obtain initial inclination rate data. The inclination rate data can be the full bending angle of the borehole formed in the unit inclination drilling footage. The dimension of the inclination rate data can include degree / meter, degree / 10 meter, degree / 100 meter, etc. Well inclination fitting can be performed directly on multiple inclination measurement data. Alternatively, outlier inclination measurement data can be filtered out from multiple inclination measurement data; well inclination fitting can be performed on the remaining inclination measurement data after filtering. The outlier inclination measurement data can be the inclination measurement data that deviates greatly from other inclination measurement data in the multiple inclination measurement data. By filtering out the outlier inclination measurement data, interference in the well inclination fitting process can be eliminated, and the accuracy of the initial inclination rate data can be improved. The well inclination fitting can include straight line fitting, and of course, can also include curve fitting. The embodiments of this specification do not make specific limitations on this.

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

[0044] In some embodiments, a drilling data set may be provided. The drilling data set may include at least one sub-data set. Each sub-data may include drilling condition data and its corresponding historical build-up rate data. The drilling condition data may include one or more of the wellbore basic data such as the designed wellbore trajectory, the drilled wellbore trajectory, the target area, the wellbore structure, the drilling tool assembly, the steering instruction, the drilling parameters, the formation category, etc. The drilling parameters may include drilling pressure, rotation speed, displacement, etc. Of course, the drilling condition data may also include other data, such as control instruction data.

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

[0046] Drilling engineering data can be collected in real time; basic wellbore data can be obtained; the basic data obtained and the collected drilling engineering data can be divided into several sub-datasets according to time periods and / or depth segments; drilling condition data and historical build-up rate data can be determined in each sub-dataset; the several sub-datasets can be included in the drilling data set. In this way, a drilling data set can be constructed. The drilling data set can be continuously enriched through accumulation. The drilling data set is used for wellbore trajectory control.

[0047] The drilling engineering data includes downhole measurement while drilling data, downhole control tool data, control instruction data, logging data, etc. The drilling engineering data is real-time data. The wellbore basic data includes the designed wellbore trajectory, the drilled wellbore trajectory, the target area, the wellbore structure, the drilling tool assembly, the steering instruction, the drilling parameters, etc. The wellbore basic data is non-real-time data.

[0048] The drilling engineering data collected in real time can be divided into time series data and depth series data. The time series data may include data that change with time, such as well depth, drill bit position, standpipe pressure, drilling pressure, hook load, torque, rotation speed, mechanical drilling speed, etc. The depth series data may include data that change with drilling depth, such as standpipe pressure, drilling pressure, hook load, torque, rotation speed, mechanical drilling speed, etc. For the convenience of analysis, the time series data can be processed according to a certain time interval (e.g., 5-30s) by average value, extreme value, normal distribution probability value, etc. to obtain a representative value within the time interval. The depth series data can be processed according to a certain depth interval (e.g., 0.1-5m) by average value, extreme value, normal distribution probability value, etc. to obtain a representative value within the depth interval.

[0049] A time period can be set at each interval, and the drilling engineering data collected within the time period and the basic wellbore data matching the collected drilling engineering data can be counted into a sub-dataset. Among them, the drilling engineering data collected within the time period and the basic wellbore data matching the collected drilling engineering data can be directly counted into a sub-dataset. Alternatively, the representative value within the time period and the basic wellbore data matching the collected drilling engineering data can also be counted into a sub-dataset. The set time period can include 1 minute, 2 minutes, 10 minutes, etc. Of course, a depth section can also be set at each interval, and the data collected within the depth section and the basic wellbore data matching the collected data can be counted into a sub-dataset. The depth section can include 1 meter, 2 meters, 10 meters, etc. In this way, several sub-datasets are obtained.

[0050] Each sub-dataset may include multiple drilling engineering data and corresponding borehole basic data. Therefore, for each sub-dataset, the build-up rate data can be calculated based on the inclination data in the multiple drilling engineering data in the sub-dataset as the historical build-up rate data in the sub-dataset; one or more of the borehole basic data can be used as drilling condition data, or one or more of the borehole basic data and control instruction data can also be used as drilling condition data.

[0051] The process of calculating the historical slope rate data can refer to the aforementioned process of calculating the initial slope rate data, which will not be repeated here.

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

[0053] It should be noted that, by matching in the drilling data set, one or more target sub-data sets can be obtained; and one or more historical build-up rate data can be obtained from the one or more target sub-data sets.

[0054] It should also be noted that one or more of the wellbore basic data such as the designed wellbore trajectory, the drilled wellbore trajectory, the target area, the wellbore structure, the drilling tool assembly, the steering instruction, the drilling parameters, the formation category, etc. can be obtained as the drilling condition data. Of course, the control instruction data in the drilling engineering data can also be further obtained as the drilling condition data.

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

[0056] In some embodiments, the calculated initial build rate data may be inaccurate due to factors such as instrument performance, formation, and length of the drilling section. For this reason, the historical build rate data can be used as a reference to compare and evaluate the initial build rate data with the historical build rate data under the same drilling conditions to obtain the actual build rate data. Compared with the initial build rate data, the actual build rate data is more consistent with the actual situation because the historical build rate data under the same drilling conditions are taken into account.

[0057] In some embodiments, actual build rate data may be calculated based on historical build rate data and initial build rate data. For example, an average value, a median value, etc. of the historical build rate data and the initial build rate data may be calculated as the actual build rate data.

[0058] In some embodiments, through step 23, a historical build rate data can be obtained. Then the deviation between the historical build rate data and the initial build rate data can be calculated; if the deviation is less than or equal to the set threshold, it means that the initial build rate data is relatively accurate, and the initial build rate data can be used as the actual build rate data; if the deviation is greater than the set threshold, it means that the accuracy of the initial build rate data is poor, and the initial build rate data can be corrected according to the historical build rate data to obtain the actual build rate data. Among them, the deviation can include the difference between the historical build rate data and the initial build rate data. Of course, other numerical values ​​can also be used to represent the deviation, and this specification embodiment does not specifically limit this. The correction may include: calculating the average value, median, etc. of the historical build rate data and the initial build rate data as the actual build rate data. In this way, the actual build rate data can be determined according to the deviation between the historical build rate data and the initial build rate data. Try to follow the initial build rate data to determine the actual build rate data, so that the actual build rate data is more in line with the actual situation.

[0059] In some embodiments, through step 23, multiple historical build rate data can be obtained. Then, the build rate interval where the preset proportion of historical build rate data is located can be obtained; it can be determined whether the initial build rate data is within the build rate interval; if so, it means that the initial build rate data is relatively accurate, and the initial build rate data can be determined as the actual build rate data; if not, it means that the accuracy of the initial build rate data is poor, and the initial build rate data can be corrected according to the build rate interval to obtain the actual build 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 build rate data can be determined; and the interval corresponding to the confidence level in the interval distribution can be obtained as the build rate interval. In some scenario examples, the correction may include: determining representative build rate data according to the build rate interval, and determining actual build rate data according to the representative build rate data and the initial build rate data. The representative build rate data can be selected from the build rate interval. Alternatively, the representative build rate data can also be calculated based on the build rate interval. For example, the representative build rate data may include the median of the build rate interval. Specifically, the average value, median, etc. of the representative build rate data and the initial build rate data can be calculated as the actual build rate data. In this way, the actual build rate data can be a numerical value. In other scenario examples, the correction may include: generating a new build rate interval as the actual build rate data according to the build rate interval and the initial build rate data. In this way, the actual build rate data can be a numerical interval. For example, representative build rate data may be determined according to the build rate interval; the representative build rate data and initial build rate data may be used as upper and lower boundaries; and the new build rate interval may be determined according to 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, the build rate deviation data can be calculated based on the actual build rate data and the designed build rate data; the build rate deviation level can be determined based on the build rate deviation data as the drilling deviation level. The build rate deviation level is positively correlated with the size of the build rate deviation data. Among them, the designed build rate data can be the planned and designed build rate data. The actual build rate data can be a numerical value. The deviation can include the difference between the designed build rate data and the actual build rate data. Alternatively, the actual build rate data can also be a numerical interval. The deviation can include the difference between the designed build rate data and the numerical interval. For example, the difference between the designed build rate data and the upper and lower boundaries of the numerical interval can be calculated respectively, and the smallest of the two differences can be selected as the difference between the designed build rate data and the numerical interval.

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

[0064] The build rate deviation level can be selected from the build rate deviation level set. Specifically, the build rate deviation data can be matched with the build rate deviation intervals corresponding to each build rate deviation level to obtain the build rate deviation interval where the build rate deviation data is located; and the build rate deviation level corresponding to the build rate deviation interval can be obtained as the drilling deviation level.

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

[0066] The drilled wellbore trajectory can be extended according to the actual build-up rate data to obtain the wellbore trajectory of the future set length. The maximum distance between the predicted wellbore trajectory and the designed wellbore trajectory can be calculated as the trajectory deviation data.

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

[0068] The trajectory deviation level may be selected from the trajectory deviation level set. Specifically, the trajectory deviation data may be matched with the trajectory deviation interval corresponding to each trajectory deviation level to obtain the trajectory deviation interval where the trajectory deviation data is located; and the trajectory deviation level corresponding to the trajectory deviation interval may be obtained as the drilling deviation level.

[0069] In some embodiments, the build rate deviation level can be determined based on the build rate deviation data; the wellbore trajectory of the set length in the future can be predicted based on the actual build rate data; the 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; the drilling deviation level can be determined based on the build rate deviation level and the trajectory deviation level. In this way, the build rate deviation and trajectory deviation are comprehensively considered, and the drilling deviation level can be determined more accurately, so that the wellbore trajectory can be controlled more accurately and the deviation can be reduced.

[0070] The process of determining the build rate deviation level and the trajectory deviation level can refer to the above-mentioned embodiment, which will not be described here. In addition, the level of drilling deviation is positively correlated with the size of the actual deviation.

[0071] The smallest or largest one of the build-up rate deviation level and the trajectory deviation level may be selected as the drilling deviation level.

[0072] Alternatively, the level difference between the build rate deviation level and the trajectory deviation level can also be determined; if the level difference is less than or equal to the set threshold, the trajectory deviation level can be used as the drilling deviation level; if the level difference is greater than or equal to the set threshold, the trajectory deviation level can be corrected according to the build rate deviation level to obtain the drilling deviation level. For example, a deviation level between the build rate deviation level and the trajectory deviation level can be selected as the drilling deviation level. The selected deviation level can specifically be any deviation level between the build rate deviation level and the trajectory deviation level. Of course, the deviation level can also be selected according to certain rules. The embodiments of this specification do not specifically limit this.

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

[0074] In some embodiments, the drilling deviation level determined in step 25 can be matched in the control strategy set to obtain the target wellbore trajectory control strategy; the target wellbore trajectory control strategy can be executed. Wherein, 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 wellbore trajectory control strategy, the second wellbore trajectory control strategy, and the third wellbore trajectory control strategy may correspond to one or more drilling deviation levels, respectively. The drilling deviation level corresponding to the first wellbore trajectory control strategy is less 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 less than the drilling deviation level corresponding to the third wellbore trajectory control strategy.

[0075] The first wellbore trajectory control strategy corresponds to a very small drilling deviation level. The first wellbore trajectory control strategy is used to keep the current control instruction unchanged to maintain the status quo. Execution of the first wellbore trajectory control strategy does not produce any action.

[0076] The drilling deviation level corresponding to the second wellbore trajectory control strategy is slightly larger. The second wellbore trajectory control strategy is used to adjust the drilling parameters so that the future wellbore trajectory is close to the designed wellbore trajectory. Then the execution of the second wellbore trajectory control strategy can generate prompt information, which can be sent to the ground equipment. The prompt information is used to prompt the business personnel to adjust the drilling parameters. The business personnel can enter the control instructions in the ground equipment according to the prompt information. The ground equipment can receive the control instructions entered by the business personnel and send the control instructions to the downhole equipment. The control instructions are used to instruct the downhole equipment to adjust the drilling parameters. Alternatively, the execution of the second wellbore trajectory control strategy can also directly generate control instructions, which can be sent to the ground equipment. The ground equipment can receive and send control instructions to the downhole equipment. The control instructions are used to instruct the downhole equipment to adjust the drilling parameters. In this way, automatic control of the wellbore trajectory can be achieved.

[0077] The drilling deviation level corresponding to the third wellbore trajectory control strategy is relatively large. The future wellbore trajectory cannot be made close to the designed wellbore trajectory only by adjusting the drilling parameters. Then executing the third wellbore trajectory control strategy can generate an alarm message, and the alarm message can be sent to the ground equipment. The alarm message is used to prompt the business personnel to redesign the wellbore trajectory. For example, the wellbore trajectory can be redesigned according to the current position and target area. The business personnel can input the redesigned wellbore trajectory into the ground equipment. The ground equipment can receive and send the redesigned wellbore trajectory to the trajectory guidance system. In addition, the business personnel can also input new control instructions into the ground equipment. The ground equipment can receive and send the new control instructions to the downhole equipment. The new control execution is used to enable the downhole equipment to follow the redesigned wellbore trajectory for drilling.

[0078] The borehole trajectory control method of the embodiment of this specification can collect drilling engineering data during the drilling process, and the drilling engineering data includes inclination data; the initial inclination rate data can be calculated based on the collected inclination data; the historical inclination rate data under the same drilling conditions as the initial inclination rate data can be queried; the actual inclination rate data can be determined based on the historical inclination rate data and the initial inclination rate data; the drilling deviation level can be determined based on the actual inclination rate data and the designed inclination rate data; and the corresponding borehole trajectory control strategy can be executed based on the drilling deviation level. In this way, the drilling deviation level can be obtained by analyzing the drilling engineering data, and the corresponding borehole trajectory control strategy can be executed for feedback correction. Thereby, automated borehole trajectory control is realized, which can improve the efficiency and accuracy of borehole trajectory control, reduce manual workload, and reduce drilling risks.

[0079] The borehole trajectory control method of the embodiment of this specification can collect drilling engineering data such as drilling measurement and borehole trajectory in real time during the directional drilling process, automatically analyze, plan, and decide the optimal drilling route, automatically control the directional drilling tool, and realize closed-loop drilling. It realizes the technology of achieving geological engineering goals automatically, reliably, and with high quality with the highest efficiency and the least manpower.

[0080] See also Figure 3 The embodiment of this specification also provides a wellbore trajectory control device, including:

[0081] The acquisition unit 31 is used to acquire drilling engineering data during the drilling process, wherein the drilling engineering data includes inclination measurement data;

[0082] A calculation unit 32, used for calculating initial slope rate data according to the collected inclination measurement data;

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

[0084] A first determining unit 34 is used to determine actual build rate data according to historical build rate data and initial build rate data;

[0085] A second determination unit 35 is used to determine the drilling deviation level according to the actual build-up rate data and the designed build-up rate data;

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

[0087] The embodiment of the present 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 implements the wellbore trajectory control method when executing the computer program.

[0088] The embodiments of the present specification also provide a computer-readable storage medium, wherein the computer-readable storage medium stores a computer program, and when the computer program is executed by a processor, the wellbore trajectory control method described above is implemented.

[0089] The embodiments of the present specification also provide a computer program product, which includes a computer program, and when the computer program is executed by a processor, the wellbore trajectory control method is implemented.

[0090] Those skilled in the art will appreciate that this specification may be provided as a method, system, or computer program product. Therefore, this specification may take the form of a complete hardware embodiment, a complete software embodiment, or an embodiment combining software and hardware. Moreover, this specification may take the form of a computer program product implemented 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 the flowcharts and / or block diagrams of the methods, devices (systems), and computer program products of the embodiments of this specification. It should be understood that each process and / or box in the flowchart and / or block diagram, as well as the combination of the processes and / or boxes in the flowchart and / or block diagram, can be implemented by computer program instructions. The computer can be a personal computer, a laptop computer, a cellular phone, a camera phone, a smart phone, a personal digital assistant, a media player, a navigation device, an email device, a game console, a tablet computer, a wearable device, or a combination of any of these devices.

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

[0093] Those skilled in the art will understand that the description of each embodiment in this specification has its own emphasis. For parts not described in detail in a certain embodiment, reference can be made to the relevant description of other embodiments. In addition, it is understood that after reading this specification, those skilled in the art can think of any combination of some or all of the embodiments listed in this specification without creative work, and these combinations are also within the scope of disclosure and protection of this specification.

[0094] Although the present specification is described by way of examples, it is known to those skilled in the art that the above examples are only used to help understand the core idea of ​​the present specification. It is understood by those skilled in the art that there are many variations and changes in the present specification. It is hoped that the appended claims include these variations and changes without departing from the spirit of the present specification.

Claims

1. A wellbore trajectory control method, characterized in that: include: Collecting drilling engineering data during the drilling process, wherein the drilling engineering data includes inclination survey data; Calculate the initial slope rate data based on the collected inclination data; Query the historical build rate data under the same drilling conditions as the initial build rate data; Determine the actual build-up rate data based on the historical build-up rate data and the initial build-up rate data; Determine the drilling deviation level based on the actual build-up rate data and the designed build-up rate data; According to the drilling deviation level, the corresponding wellbore trajectory control strategy is executed.

2. The method according to claim 1, characterized in that The number of the drilling engineering data is multiple; The steps to calculate the initial build rate data include: The well inclination is fitted on multiple inclination survey data to obtain the initial inclination rate data.

3. The method according to claim 1, characterized in that The steps for querying historical build rate data include: Acquire drilling condition data corresponding to the drilling engineering data; According to the drilling condition data, matching is performed in the drilling data set to obtain a target sub-data set; the drilling data set includes at least one sub-data set, each sub-data set includes the drilling condition data and its corresponding historical build-up rate data; Get the historical build rate data in the target sub-dataset.

4. The method according to claim 1, characterized in that The method further comprises: Real-time collection of downhole measurement while drilling data, downhole control tool data, control instruction data, and logging data; Obtain basic wellbore data; Divide the acquired basic data and real-time collected data into several sub-datasets according to time periods and / or depth segments; determining drilling condition data and historical build rate data within each sub-dataset; The plurality of sub-data sets are included in the drilling data set.

5. The method according to claim 1, characterized in that The number of the historical build rate data is multiple; The steps to determine the actual build rate data include: Obtain the build rate interval where the historical build rate data of a preset proportion is located; Determining whether the initial build rate data is within the build rate interval; If yes, the initial build rate data is determined as the actual build rate data; If not, the initial build rate data is corrected according to the build rate interval to obtain actual build rate data.

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

7. The method according to claim 1, characterized in that The steps of executing the wellbore trajectory control strategy include: Matching the drilling deviation level in the control strategy set to obtain a target wellbore trajectory control strategy, wherein the control strategy set includes a plurality of wellbore trajectory control strategies, each wellbore trajectory control strategy corresponding to a drilling deviation level; Execute 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 instructions unchanged; the second wellbore trajectory control strategy is used to indicate adjusting the drilling parameters to correct the actual wellbore trajectory; 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: A collection unit, used for collecting drilling engineering data during the drilling process, wherein the drilling engineering data includes inclination measurement data; A calculation unit, used for calculating initial slope rate data according to the collected inclination measurement data; A query unit, used to query historical build-up rate data under the same drilling conditions as the initial build-up rate data; A first determination unit is used to determine actual build rate data according to historical build rate data and initial build rate data; A second determination unit is used to determine the drilling deviation level according to 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; a memory for storing processor-executable instructions; The processor implements the method according to any one of claims 1 to 8 by executing the instructions.

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