A method, device, equipment, medium and product for calculating well drilling inclination data

Abstract

Embodiments of the present application provide a drilling inclination data calculation method, device, equipment, medium and product, and relate to the field of oil and gas field development. The method comprises: acquiring a plurality of first inclination data, a plurality of second inclination data and a plurality of magnetic ranging data; performing coordinate conversion on the plurality of second inclination data to obtain a plurality of first coordinates; performing coordinate correction on the plurality of first coordinates according to the plurality of magnetic ranging data to obtain a plurality of second coordinates; and fitting the plurality of first inclination data and the plurality of second coordinates to obtain a plurality of third inclination data. The method combines the inclination data of the drilled well and the magnetic ranging data of the drilling well, uses coordinate conversion and correction technology to invert the inclination data of the horizontal section of the drilling well, and then fuses the inclination data of the drilled part of the drilling well, so as to construct the trajectory data of the complete drilling well, thereby solving the problem that the inclination data of the drilling well cannot be directly and accurately obtained when close to the drilled well.

Description

Technical Field

[0001] This application relates to the field of oil and gas field development, and in particular to a method, apparatus, equipment, medium and product for calculating drilling survey data. Background Technology

[0002] Inclination data describes the spatial location and direction of a drilling well, primarily including depth, inclination angle, and azimuth, and is used to characterize the well's trajectory during drilling. As oil and gas field development extends to deeper and more complex geological formations, the requirements for well trajectory control accuracy are increasing. This necessitates not only real-time monitoring of the trajectory characteristics of the drilled section but also accurate prediction of the direction of the section being drilled. Against this backdrop, establishing a high-precision inclination data calculation method to achieve accurate characterization of the entire well trajectory has become a key issue in improving the quality and efficiency of drilling engineering.

[0003] Existing magnetic ranging technology has the problem of not being able to directly obtain wellbore deviation data during drilling. Downhole sensors can only measure data such as the inclination angle and azimuth of well sections that are relatively far from the drilled well, and cannot directly and accurately collect data such as the inclination angle and azimuth of well sections that are relatively close to the drilled well. Although magnetic ranging data can provide some reference, this parameter cannot be equivalent to deviation data, resulting in a lag in trajectory control during actual drilling.

[0004] The aforementioned limitations result in a significant lag in trajectory control during actual drilling. This lag presents serious technical challenges and potential risks: First, it significantly increases the difficulty of wellbore collision prevention, especially in areas with dense well networks, where inaccurate trajectory prediction may lead to collisions with adjacent wells, causing safety accidents. Second, it reduces the efficiency and accuracy of drilling operations; when the trajectory deviates from the design target, additional time and costs are required for adjustments, extending the drilling cycle. Finally, it may cause the drill bit to fail to accurately hit the target reservoir, affecting the final extraction effect and economic benefits of the oil and gas field. Therefore, how to overcome the shortcomings of existing technologies and achieve real-time, accurate prediction of the trajectory throughout the entire drilling process is a technical problem that urgently needs to be solved in this field. Summary of the Invention

[0005] This application provides a method, apparatus, equipment, medium, and product for calculating drilling survey data, in order to solve the problem in the prior art that it is impossible to accurately collect survey data of the drilling section that is close to the already drilled well.

[0006] In a first aspect, embodiments of this application provide a method for calculating drilling survey data, including:

[0007] S1. Acquire multiple first inclination measurement data, multiple second inclination measurement data, and multiple magnetic distance measurement data; wherein, the multiple first inclination measurement data refers to the inclination measurement data of the drilled portion of the well being drilled, the multiple second inclination measurement data refers to the inclination measurement data of the drilled well, and the multiple magnetic distance measurement data is used to represent the relative distance between the magnetic sub in the well being drilled and the probe in the drilled well;

[0008] S2. The plurality of second inclination data are transformed to obtain a plurality of first coordinates; wherein the plurality of first coordinates are used to represent the spatial trajectory of the drilled well;

[0009] S3. Based on the multiple magnetic ranging data, the multiple first coordinates are corrected to obtain multiple second coordinates; wherein, the multiple second coordinates are used to represent the spatial trajectory of the subsequent drilling section of the well.

[0010] S4. Fit the plurality of first inclination data and the plurality of second coordinates to obtain a plurality of third inclination data; wherein, the plurality of third inclination data refers to the inclination data of the drilling operation.

[0011] Secondly, embodiments of this application provide a drilling survey data calculation device, comprising:

[0012] The acquisition module is used to acquire multiple first inclination measurement data, multiple second inclination measurement data, and multiple magnetic ranging data; wherein, the multiple first inclination measurement data refers to the inclination measurement data of the drilled portion of the well being drilled, the multiple second inclination measurement data refers to the inclination measurement data of the drilled well, and the multiple magnetic ranging data is used to represent the relative distance between the magnetic sub in the well being drilled and the probe in the drilled well;

[0013] A coordinate transformation module is used to transform the multiple second inclination data to obtain multiple first coordinates; wherein the multiple first coordinates are used to represent the spatial trajectory of the drilled well;

[0014] The coordinate correction module is used to correct the multiple first coordinates based on the multiple magnetic ranging data to obtain multiple second coordinates; wherein the multiple second coordinates are used to represent the spatial trajectory of the subsequent drilling section of the well.

[0015] The fitting module is used to fit the plurality of first inclination data and the plurality of second coordinates to obtain a plurality of third inclination data; wherein, the plurality of third inclination data refers to the inclination data of the drilling operation.

[0016] Thirdly, this application provides an electronic device, including: a processor, and a memory communicatively connected to the processor;

[0017] The memory stores computer-executed instructions;

[0018] When the processor executes the computer execution instructions stored in the memory, it is used to implement a method for calculating drilling survey data as described in any of the first aspects.

[0019] Fourthly, this application provides a computer-readable storage medium storing computer-executable instructions, which, when executed by a processor, are used to implement a method for calculating drilling survey data as described in any of the first aspects.

[0020] Fifthly, this application provides a computer program product, including a computer program, which, when executed by a processor, is used to implement a method for calculating drilling survey data as described in any of the first aspects.

[0021] This application provides a method, apparatus, equipment, medium, and product for calculating drilling directional measurement data. The method includes: acquiring multiple first directional measurement data, multiple second directional measurement data, and multiple magnetic ranging data; wherein the multiple first directional measurement data refers to the directional measurement data of the drilled portion of the well, the multiple second directional measurement data refers to the directional measurement data of the drilled well, and the multiple magnetic ranging data is used to represent the relative distance between the magnetic sub and the probe in the drilled well; performing coordinate transformation on the multiple second directional measurement data to obtain multiple first coordinates; wherein the multiple first coordinates are used to represent the spatial trajectory of the drilled well; performing coordinate correction on the multiple first coordinates based on the multiple magnetic ranging data to obtain multiple second coordinates; wherein the multiple second coordinates are used to represent the spatial trajectory of the subsequent drilling section of the well; fitting the multiple first directional measurement data and the multiple second coordinates to obtain multiple third directional measurement data; wherein the multiple third directional measurement data refers to the directional measurement data of the drilled well. The method for calculating wellbore survey data in this application combines survey data from existing wells with magnetic ranging data from the ongoing drilling process. It uses coordinate transformation and correction techniques to invert the survey data of the horizontal section of the ongoing drilling process, and then fuses it with the survey data of the already drilled portion of the ongoing drilling process to construct complete trajectory data of the ongoing drilling process. This method solves the problem that conventional sensors become inaccurate when close to existing wells, resulting in the inability to accurately obtain survey data for that section of the ongoing drilling process. It provides reliable technical support for efficient drilling under complex geological conditions. Attached Figure Description

[0022] The accompanying drawings, which are incorporated in and form part of this specification, illustrate embodiments consistent with this application and, together with the description, serve to explain the principles of this application.

[0023] Figure 1 This is a schematic diagram illustrating an application scenario of the method for calculating drilling survey data provided in the embodiments of this application;

[0024] Figure 2 A flowchart illustrating the method for calculating drilling survey data provided in the embodiments of this application. Figure 1 ;

[0025] Figure 3 A flowchart illustrating the method for calculating drilling survey data provided in the embodiments of this application. Figure 2 ;

[0026] Figure 4 A schematic diagram of the structure of the drilling survey data calculation device provided in the embodiments of this application;

[0027] Figure 5 This is a schematic diagram of the hardware structure of the electronic device provided in the embodiments of this application.

[0028] The accompanying drawings illustrate specific embodiments of this application, which will be described in more detail below. These drawings and descriptions are not intended to limit the scope of the concept in any way, but rather to illustrate the concept of this application to those skilled in the art through reference to particular embodiments. Detailed Implementation

[0029] Exemplary embodiments will now be described in detail, examples of which are illustrated in the accompanying drawings. When the following description relates to the drawings, unless otherwise indicated, the same numbers in different drawings denote the same or similar elements. The embodiments described in the following exemplary embodiments do not represent all embodiments consistent with this application. Rather, they are merely examples of apparatuses and methods consistent with some aspects of this application as detailed in the appended claims.

[0030] In this application embodiment, the terms "first" and "second" are used to distinguish identical or similar items with substantially the same function and effect. Those skilled in the art will understand that the terms "first" and "second" do not limit the quantity or execution order, and that "first" and "second" do not necessarily imply difference. It should be noted that in this application embodiment, the words "exemplary" or "for example" are used to indicate that something is being used as an example, illustration, or description. Any embodiment or design scheme described as "exemplary" or "for example" in this application should not be construed as being better or more advantageous than other embodiments or design schemes. Specifically, the use of "exemplary" or "for example" is intended to present the relevant concepts in a concrete manner. In this application embodiment, "at least one" refers to one or more, and "more than one" refers to two or more.

[0031] It should be noted that the phrase "at...time" in the embodiments of this application can refer to the instant at which a certain situation occurs, or to a period of time after the occurrence of a certain situation; the embodiments of this application do not specifically limit this. Furthermore, the method, apparatus, equipment, medium, and product for calculating drilling directional data provided in the embodiments of this application are merely examples; a method, apparatus, equipment, medium, and product for calculating drilling directional data may also include more or fewer elements.

[0032] To facilitate a clear description of the technical solutions in the embodiments of this application, some terms and technologies involved in the embodiments of this application will be briefly introduced below:

[0033] Inclination data consists of fundamental measurement parameters that record the shape of the drilling trajectory. These parameters primarily include depth information along the wellbore direction, the angle of deviation of the wellbore from the vertical direction, and the orientation of the wellbore's horizontal extension. This data acts as navigation coordinates for the drilling operation. Through continuous acquisition and analysis, the three-dimensional spatial orientation of the underground wellbore can be accurately depicted, providing trajectory control for drilling operations and ensuring that the drill bit accurately reaches the target formation along the designed path, while avoiding collisions with adjacent wellbores.

[0034] Magnetic ranging data is a technical method for measuring the relative distance and orientation of a well and a detection device through the interaction of their magnetic fields. In drilling operations, when casing or magnetic markers exist in adjacent wellbores, this data reflects the spatial relative position between the new well being drilled and existing neighboring wells. It is primarily used for real-time monitoring of wellbore collision avoidance distances, ensuring safe drilling of two or more wells in complex formations without collisions. Its principle is based on the physical characteristic that magnetic field strength varies with distance; by analyzing the magnetic field signal, the spatial offset direction and distance between the two wells can be calculated.

[0035] Drilling trajectory curve: This is a three-dimensional spatial curve reflecting the actual drilling path of the underground wellbore. This curve is formed by connecting continuous inclination measurement data points, visually showing the complete trajectory of the wellbore from the surface entrance to the target formation underground, including the curvature, inclination direction, and horizontal extension trend of the wellbore. It serves as both the navigation trajectory for drilling operations and an important basis for verifying whether the preset target formation has been accurately reached. It plays a crucial role in ensuring drilling safety, avoiding wellbore collisions, and optimizing oil and gas extraction.

[0036] Exemplary embodiments will now be described in detail, examples of which are illustrated in the accompanying drawings. When the following description relates to the drawings, unless otherwise indicated, the same numerals in different drawings denote the same or similar elements. The embodiments described in the following exemplary embodiments do not represent all embodiments consistent with the present invention. Rather, they are merely examples of apparatuses and methods consistent with some aspects of the invention as detailed in the appended claims.

[0037] The technical solution of the present invention will be described in detail below with reference to specific embodiments. These specific embodiments can be combined with each other, and the same or similar concepts or processes may not be described again in some embodiments. The embodiments of the present invention will now be described with reference to the accompanying drawings.

[0038] To clearly understand the technical solution of this application, the existing technical solutions will first be described in detail. As oil and gas field development extends to deeper and more complex structural areas, the requirements for well trajectory control accuracy are increasing. This necessitates not only real-time monitoring of the trajectory characteristics of the drilled section but also accurate prediction of the direction of the drilling phase. Against this backdrop, establishing a high-precision method for calculating directional measurement data to achieve accurate depiction of the trajectory throughout the entire well section has become a key issue in improving the quality and efficiency of drilling engineering.

[0039] However, downhole sensors can only measure data such as the inclination angle and azimuth of the drilling section that is far from the drilled well, and cannot directly and accurately collect data such as the inclination angle and azimuth of the drilling section that is close to the drilled well. Although magnetic ranging data can provide some reference, this parameter cannot be equivalent to the inclination measurement data, resulting in a lag in trajectory control during actual drilling. Therefore, the existing technology has the problem of not being able to accurately collect inclination measurement data of the drilling section that is close to the drilled well.

[0040] Therefore, addressing the problem of inaccurate acquisition of wellbore survey data for sections close to existing wells in current drilling, the research found that to solve this problem, accurate calculation of survey data can be achieved by fusing measured data from current drilling wells with trajectory information from adjacent wells, combined with dynamic correction of magnetic ranging and intelligent fitting algorithms: ① A spatial mapping relationship between current drilling sensor data and historical trajectories of adjacent wells can be established, using magnetic ranging technology to dynamically correct instrument errors, and an adaptive curve fitting algorithm to construct a real-time calculation model of the downhole three-dimensional trajectory. ② The weighting coefficients of different measurement parameters can be automatically adjusted according to changes in well depth, emphasizing magnetic azimuth correction in the build-up section and prioritizing inertial navigation data in the stabilization section, combined with spatial geometric constraints of adjacent well trajectories, to achieve a balance between calculation accuracy and efficiency. ③ The raw survey data can be rapidly preprocessed to identify key measurement points, and then refined calculations and error compensation can be performed on key well sections, achieving a smooth transition of the entire well trajectory through spatial interpolation technology.

[0041] Specifically, real-time measurement data from the drilling operation can be integrated with historical trajectory information from adjacent wells. By combining dynamic measurement correction technology, an intelligent calculation model can be constructed. A reference trajectory can be established using spatial coordinate transformation and error compensation algorithms. The trajectory calculation for subsequent drilling sections can be optimized through an intelligent correction mechanism. Finally, an adaptive fitting algorithm can be used to achieve high-precision reconstruction of the trajectory for the entire well section. The well's inclination measurement data can be obtained through the constructed trajectory map.

[0042] This application discloses a method, apparatus, equipment, medium, and product for calculating wellbore survey data. By combining survey data from already drilled wells with magnetic ranging data from ongoing drilling, and using coordinate transformation and correction techniques to invert the survey data for the subsequent drilling section of the ongoing drilling, this method then merges the survey data with the survey data from the already drilled section of the ongoing drilling to construct complete trajectory data for the ongoing drilling, including the subsequent drilling section. This solves the problem of not being able to directly and accurately obtain wellbore survey data when approaching an already drilled well, and provides reliable technical support for efficient drilling under complex geological conditions.

[0043] Based on the above-mentioned inventive discovery, the technical solution of this application is proposed.

[0044] The following describes the application scenarios of the drilling directional measurement data calculation method provided in the embodiments of the present invention. Figure 1 This is a schematic diagram illustrating an application scenario of the method for calculating drilling survey data provided in this application embodiment. For example... Figure 1 As shown, the application scenario includes a mobile terminal 101 and a server 102. The mobile terminal 101 acquires multiple first inclination measurement data, multiple second inclination measurement data, and multiple magnetic ranging data, and sends these data to the server 102. The server 102 first performs coordinate transformation on the multiple second inclination measurement data to obtain multiple first coordinates. Then, the server 102 performs coordinate correction on the multiple first coordinates based on the multiple magnetic ranging data to obtain multiple second coordinates. Finally, the server 102 fits the multiple first inclination measurement data and the multiple second coordinates to obtain the inclination measurement data for the drilling operation.

[0045] The embodiments of the present invention will now be described with reference to the accompanying drawings.

[0046] Figure 2 A flowchart illustrating the method for calculating drilling survey data provided in the embodiments of this application. Figure 1 .like Figure 2 As shown, in this embodiment, the execution entity of this invention is a server. The method for calculating drilling survey data provided in this embodiment includes the following steps:

[0047] S201. Acquire multiple first inclination measurement data, multiple second inclination measurement data, and multiple magnetic distance measurement data; wherein, the multiple first inclination measurement data refers to the inclination measurement data of the drilled part of the well being drilled, the multiple second inclination measurement data refers to the inclination measurement data of the drilled well, and the multiple magnetic distance measurement data is used to represent the relative distance between the magnetic short section in the well being drilled and the probe in the drilled well.

[0048] Specifically, the inclination angle and azimuth information of the drilling section can be acquired in real time using measurement-while-drilling (MWD) instruments as the first inclination measurement data. Simultaneously, trajectory measurement results of adjacent wells are extracted from the historical records of completed wells as the second inclination measurement data. Furthermore, the electromagnetic induction characteristics between a magnetic marker mounted on the drill string and a detection device in the casing of an adjacent well are used to measure the distance between the two wells as magnetic ranging data. This step establishes a complete spatial reference system for well trajectory calculation. By integrating information from the current drilling status, the actual trajectory of adjacent wells, and the relative positions between wells, it provides accurate and reliable basic data support for subsequent collision avoidance analysis.

[0049] S202. Perform coordinate transformation on multiple second inclination data to obtain multiple first coordinates; among them, the multiple first coordinates are used to represent the spatial trajectory of the drilled well.

[0050] Specifically, historical directional survey data from adjacent wells can be transformed using spatial coordinate transformation methods. This recalculates the original measurement data, which was based on the wellhead of the adjacent well, into a three-dimensional coordinate system with the current wellhead as the reference point, thus obtaining the first coordinate under a unified spatial reference. This step eliminates the differences between measurement references from different wellbores, establishes a unified inter-well spatial relationship model, and allows adjacent well trajectory data to be compared, analyzed, and calculated with current drilling data in the same coordinate system, providing an accurate spatial reference for subsequent trajectory determination.

[0051] For example, the minimum curvature method can be used to convert multiple second inclinometer data into... NEV coordinate, NEV A coordinate system is a rectangular coordinate system based on geographic direction, and its name comes from the three coordinate axes: north (…). North , N ),East( East , E ) and pointing vertically downwards towards the Earth's center ( Vertical , V This coordinate system uses the current position as its origin and extends through... X The axis points to geographic due north. Y The axis points due east. Z The axes are perpendicularly downwards to form a right-handed rectangular coordinate system, which is often used for drilling trajectory calculation.

[0052] Let the first well on the already drilled trajectory be... i The depth measurement at each measuring point is The well inclination angle is azimuth angle is The formula for calculating the difference in well depth between any two measuring points is:

[0053] ,

[0054] in, The difference in well depth between two adjacent measuring points. and This represents the well depth between two adjacent measuring points.

[0055] The formula for calculating the dogleg angle between two adjacent measuring points is:

[0056] ,

[0057] ,

[0058] in, and This refers to the well inclination angle between two adjacent measuring points. and It refers to the azimuth angle between two adjacent measuring points. It is the dogleg angle. The dogleg angle refers to the angle between the wellbore direction lines at two adjacent measuring points in the drilling trajectory in three-dimensional space. It is used to quantitatively describe the degree of spatial curvature of the wellbore trajectory within a unit well section.

[0059] The formula for calculating the correction factor is:

[0060] ,

[0061] in, For correction factor, This represents the difference in well depth between two adjacent measuring points. The correction factor is used to correct the nonlinear coupling effect of the rate of change of well inclination and azimuth between adjacent measuring points, making it closer to the actual curvature of the wellbore trajectory in three-dimensional space.

[0062] The formula for calculating the NEV coordinate increment between two adjacent measuring points is:

[0063] ,

[0064] ,

[0065] ,

[0066] in, For correction factor, and This refers to the well inclination angle between two adjacent measuring points. and It refers to the azimuth angle between two adjacent measuring points. , and The first i The northward, eastward, and vertical increments of each measuring point. (This refers to the increments of a given measuring point in the north, eastward, and vertical directions.) NEV Coordinates plus this measuring point NEV The coordinate increment will give the next measurement point. NEV coordinate.

[0067] S203. Based on multiple magnetic ranging data, the coordinates of multiple first coordinates are corrected to obtain multiple second coordinates; wherein, the multiple second coordinates are used to represent the spatial trajectory of the subsequent drilling section of the well.

[0068] Specifically, by combining the actual well spacing information reflected by magnetic ranging data, a spatial geometric correction algorithm can be used to dynamically adjust the initially converted coordinates of adjacent wells, ensuring that the corrected second coordinates accurately reflect the true spatial relative positions of the two wells. This step is used to eliminate coordinate deviations caused by measurement errors and geological changes, and by using magnetic ranging as a direct spatial constraint, improves the positioning accuracy of adjacent well trajectories in the current drilling coordinate system.

[0069] S204. Fit multiple first inclination measurement data and multiple second coordinates to obtain multiple third inclination measurement data; where the multiple third inclination measurement data refer to the inclination measurement data of the well in progress.

[0070] Specifically, a spatial trajectory fusion algorithm can be used to intelligently match and smoothly connect the measured wellbore inclination azimuth data of the current drilling operation with the corrected reference trajectory of adjacent wells. This generates complete inclination measurement data, including subsequent drilling sections, by establishing a three-dimensional wellbore trajectory model. This step achieves seamless integration of measured data from the drilled section with the trajectory of the subsequent drilling section, maintaining the accuracy of the measured data while reflecting the reference value of adjacent well trajectories. Ultimately, this forms a continuous trajectory description reflecting the overall drilling trend, providing comprehensive and reliable data for wellbore trajectory control.

[0071] This application provides a method for calculating wellbore survey data. By combining survey data from already drilled wells with magnetic ranging data from ongoing drilling, and using coordinate transformation and correction techniques to invert the survey data for the subsequent drilling section of the ongoing drilling, this method then merges it with the survey data from the already drilled section of the ongoing drilling to construct complete trajectory data for the ongoing drilling, including the subsequent drilling section. This solves the problem of not being able to directly and accurately obtain wellbore survey data when approaching an already drilled well, and provides reliable technical support for efficient drilling under complex geological conditions.

[0072] In one possible design, S202, coordinate transformation is performed on multiple second inclinometer data to obtain multiple first coordinates, including:

[0073] S2021. Obtain the wellhead coordinates of the drilled well; where the wellhead coordinates of the drilled well refer to the coordinates of the wellhead in the first coordinate system, and the first coordinate system refers to the global coordinate system established with the preset measurement reference point as the origin.

[0074] Specifically, the wellhead location can be mapped on-site using surveying equipment such as a total station, or directly extracted from the coordinate information marked on engineering drawings. This step is used to establish a transformation benchmark from the global coordinate system to the local coordinate system. By accurately calibrating the absolute position of the drilled wellhead, it provides crucial basic positioning information for subsequently converting adjacent well trajectory data to a unified spatial reference system, ensuring that inclination data from different sources can be accurately compared and calculated within the same spatial framework.

[0075] S2022. Perform coordinate transformation on multiple second inclination data to obtain multiple third coordinates; among them, the multiple third coordinates are the coordinates of the drilled well trajectory in the second coordinate system, which refers to the local coordinate system established with the wellhead coordinates of the drilled well as the coordinate origin.

[0076] Specifically, spatial coordinate transformation methods can be used to convert the inclination measurement data of adjacent wells from their original measurement reference to a relative coordinate system centered on the wellhead of the current well. This step is used to normalize wellbore trajectory data under different measurement conditions. By establishing a local reference frame based on a single well, the influence of differences in the original measurement reference is eliminated, providing comparable intermediate trajectory data for subsequent global coordinate system integration, and ensuring the accuracy and consistency of multi-well spatial relationship calculations.

[0077] S2023. Based on the wellhead coordinates of the drilled wells, the coordinates of multiple third coordinates are corrected to obtain multiple first coordinates.

[0078] Specifically, based on the actual position of the drilled wellhead in the global coordinate system, the well trajectory data in the local coordinate system can be transformed into a unified global reference frame through spatial translation transformation. This step is used to achieve spatial unification of different well trajectory data. By associating the independent local coordinate systems of each well with a common measurement benchmark, an overall spatial model that accurately reflects the true relative positions between wells is established, providing a reliable foundation for multi-well collaborative computing for subsequent trajectory optimization.

[0079] The technical effect of this solution in this embodiment is as follows: by introducing wellhead coordinates as a global reference point and performing the coordinate transformation process step by step, the problem of trajectory positioning deviation caused by inconsistencies in coordinate systems during traditional inclination data transformation is solved. This method first converts the inclination data of the drilled well into local coordinates with the wellhead as the origin, and then corrects it by combining the wellhead coordinates in the global coordinate system. This eliminates the transformation error between the local and global coordinate systems, ensuring accurate mapping of the drilled well's spatial trajectory. This dual coordinate correction mechanism improves the spatial consistency of the trajectory data and enhances the accuracy of overall drilling trajectory modeling.

[0080] In one possible design, S203, multiple first coordinates are corrected based on multiple magnetic ranging data to obtain multiple second coordinates, including:

[0081] S2031. Based on multiple magnetic ranging data, the position of multiple probe measuring points is calculated to obtain the position of the probe in the drilled well when the magnetic ranging measurement is performed.

[0082] Specifically, by analyzing the strength and propagation characteristics of the magnetic ranging signal and combining it with the trajectory data of the drilled wells, the exact position of the probe in the well during the measurement can be deduced. This step is used to accurately calibrate the spatial reference point for magnetic ranging measurements. By determining the actual position of the probe in the adjacent well, it provides a crucial spatial positioning reference for subsequent calculations of the precise relative azimuth and distance between the two wells, ensuring that the well spacing data on which the trajectory correction is based is accurate and reliable.

[0083] For example, based on the magnetic ranging data of the probe in the drilled well, the horizontal and vertical displacements of the magnetic sub in the drilled well relative to the measuring point of the probe in the drilling well, as well as the insertion depth of the probe in the drilled well, can be obtained. Based on the previously obtained complete data from drilled wells... NEV Coordinates for the depth of the probe run in each drilled well. Interpolation of measurement points to obtain the measurement points of the probe Coordinates. Distance along the entire trajectory after selecting interpolation. The point above the nearest depth at the measuring point For reference, local azimuth angle The calculation formula is:

[0084] ,

[0085] ,

[0086] ,

[0087] in, and For the first The northward and eastward increments of each measuring point. The azimuth angle at the measuring point corresponding to the drilling operation. It can be represented as:

[0088] ,

[0089] in, This is a local azimuth angle. This represents the displacement of the drilling point relative to the drilled point. The displacements of the drilling point relative to the drilled point in the north, east, and vertical directions are as follows:

[0090] ,

[0091] ,

[0092] ,

[0093] in, It is the vertical displacement of the drilling measurement point relative to the drilled measurement point, at the magnetic short section measurement point during drilling. Coordinates can be represented as:

[0094] ,

[0095] ,

[0096]

[0097] S2032. Calculate the angles based on the positions of multiple probe measuring points to obtain multiple azimuth angles; where the multiple azimuth angles are used to represent the extension direction of the drilled well at the multiple probe measuring point positions.

[0098] Specifically, by analyzing the spatial distribution characteristics of the probe along the drilled well trajectory and combining this with the wellbore trajectory extension trend, the extension direction of the wellbore at each measuring point can be calculated as the azimuth. This step is used to accurately capture the azimuth characteristics of adjacent wells at key measuring points. By quantifying the actual extension azimuth of the drilled wellbore at each measuring point, a directional reference is provided for subsequent calculations of the spatial relative positional relationship between the two wells, ensuring that the influence of the adjacent well's azimuth on the collision avoidance distance is fully considered when correcting the trajectory.

[0099] S2033. Calculate the spatial offset based on multiple magnetic ranging data and multiple azimuth angles; whereby the spatial offset is used to represent the relative displacement between the positions of multiple probe measuring points and multiple drilling target points, and the multiple drilling target points refer to the trajectory points on the subsequent drilling section of the drilling.

[0100] Specifically, by combining the distance between the two wells reflected in the magnetic ranging data and the wellbore direction indicated by the azimuth angle, the three-dimensional displacement of the target drilling point relative to the probe measuring point can be determined through spatial vector calculations. This step converts the linear distance information from the magnetic ranging into a directional spatial position difference. By quantifying the actual offset between the two well trajectories, it provides key spatial position adjustment parameters for subsequent accurate correction of the drilling trajectory, ensuring the accuracy of the collision avoidance analysis.

[0101] S2034. Based on the positions and spatial offsets of multiple probe measuring points, vector superposition is performed to obtain multiple second coordinates; among them, the multiple second coordinates are the coordinates of multiple positive drilling target points in the global coordinate system.

[0102] Specifically, the location of the probe measuring point can be used as a reference point, and the calculated spatial offset vector can be superimposed to determine the precise location of the drilling target point in the global coordinate system. This step is used to convert the relative distance measurement results into absolute spatial coordinates, and to achieve precise positioning from the adjacent well reference point to the drilling target point through vector synthesis, providing reliable spatial location data support for subsequent wellbore trajectory determination.

[0103] The technical effect of this solution in this embodiment is that by dynamically coupling magnetic ranging data with the azimuth of the drilled well, a spatial vector correction model is constructed, solving the relative position deviation problem caused by neglecting the directionality of the drilling trajectory in traditional methods. This method first locks the real-time position of the probe in the drilled well based on magnetic ranging, and then combines this with the precise azimuth of the wellbore extension at that position to convert the magnetic ranging data into a three-dimensional directional spatial offset. Finally, precise positioning of the trajectory points in subsequent drilling sections is achieved through vector superposition. This vector correction mechanism, which integrates distance measurement and azimuth data, improves the spatial position mapping accuracy of the drilling operation relative to the drilled well.

[0104] In one possible design, S204, multiple first inclinometer data and multiple second coordinates are fitted to obtain multiple third inclinometer data, including:

[0105] S2041. Based on multiple preset weights, fit multiple first inclination measurement data and multiple second coordinates to obtain a first positive drilling trajectory curve; wherein, the first positive drilling trajectory curve includes multiple first fitting points.

[0106] Specifically, based on the reliability and importance of different data sources, different weighting coefficients can be assigned to the directional drilling data. The two types of data are then fused and calculated using the weighted least squares method to generate a preliminary wellbore trajectory curve. This step is used to balance the contribution ratio of measured data and reference data. By considering the accuracy characteristics and spatial distribution features of different data sources, an initial trajectory model is formed that reflects the current drilling situation while also taking into account the reference value of adjacent wells.

[0107] S2042. Calculate the azimuth change rate corresponding to each first fitting point; wherein, the azimuth change rate is used to represent the degree of azimuth change between each first fitting point and its adjacent first fitting points.

[0108] Specifically, the degree of turning of the trajectory curve at each node can be quantified by analyzing the ratio of the azimuth difference between adjacent fitting points to the sounding interval. This step is used to identify sharp turns or abnormal turning sections that may exist in the well trajectory. By evaluating the steepness of local trend changes, it provides a basis for subsequent screening of key nodes that need to be optimized, ensuring that the final generated trajectory curve is both smooth and continuous and accurately reflects the actual geological steering requirements.

[0109] S2043. Calculate the spatial residual between multiple original data points and multiple first fitting points; wherein, the multiple original data points include multiple first inclinometer data and multiple second coordinates, and the spatial residual is used to represent the deviation between the multiple original data points and the multiple first fitting points.

[0110] Specifically, the straight-line distance between the original inclinometer data points and the corresponding points on the preliminary fitted trajectory can be measured as the spatial deviation. This step is used to evaluate the degree of agreement between the initial fitting results and the actual measurement data. By quantifying the magnitude of each data point's deviation from the fitted curve, sections that may have anomalies or require special attention can be identified. This provides a basis for data quality evaluation for subsequent classification optimization and iterative calculations, ensuring that the final trajectory curve both conforms to the measurement data and maintains a reasonable geological orientation trend.

[0111] S2044. Calculate the curvature normal projection of the first positive drilling trajectory curve at multiple first fitting points; wherein, the curvature normal projection is used to represent the degree to which each original data point deviates from the first positive drilling trajectory curve.

[0112] Specifically, the center of curvature of the trajectory curve at each fitting point can be determined using geometric differentiation methods. Then, the perpendicular distance from the original data point to the radius of curvature at that point is measured. This step is used to evaluate the degree to which the data point deviates from the trajectory from the perspective of the curve's curvature characteristics. By analyzing the difference between the original measurements and the fitted curve in the normal direction, abnormal curvature sections that require special attention are identified, providing a comprehensive spatial geometric feature reference for subsequent trajectory optimization.

[0113] S2045. Classify the multiple first fitting points to obtain multiple second fitting points, multiple third fitting points, and multiple fourth fitting points; wherein, multiple second fitting points refer to first fitting points whose spatial residuals are greater than a preset residual threshold and whose curvature normal projections are greater than a preset projection threshold; multiple third fitting points refer to first fitting points whose azimuth rate of change is greater than a preset rate of change threshold or whose spatial residuals are greater than a residual threshold; and multiple fourth fitting points refer to fitting points other than multiple second and multiple third fitting points among the multiple first fitting points.

[0114] Specifically, based on three characteristic indicators—the magnitude of the spatial residual, the degree of deviation from the curvature normal, and the rate of change of the azimuth angle—the initial fitting points can be divided into three categories: those requiring key correction, those requiring optimization, and those meeting the requirements. This step is used to identify abnormal segments of different natures in the trajectory curve. Through a classification and processing strategy, problem nodes are optimized in a targeted manner. While ensuring the smoothness of the overall trajectory, segments with significant deviations or sharp turns are corrected, so that the final trajectory conforms to both the measurement data and the engineering requirements.

[0115] S2046. Iterative optimization is performed on multiple third fitting points and multiple fourth fitting points to obtain the second positive drilling trajectory curve.

[0116] Specifically, a progressive optimization strategy can be adopted for different types of fitting points. Local adjustments are made to sections with abrupt changes in orientation or slight deviations, while keeping the sections that meet the requirements stable. Through multiple iterative calculations, the optimal trajectory curve is gradually approximated. This step balances the relationship between trajectory accuracy and smoothness, retaining reasonable sections by focusing on optimizing problematic nodes, ultimately forming a wellbore trajectory that reflects both measured data and engineering applicability, providing a reliable basis for drilling guidance.

[0117] S2047. Sample and calculate the second positive drilling trajectory curve to obtain multiple third inclination measurement data.

[0118] Specifically, representative locations can be selected on the optimized trajectory curve according to the required density intervals for the project. Differential geometry methods are then used to calculate the inclination and azimuth parameters at each sampling point. This step transforms the continuous spatial trajectory curve into a discrete, standard inclinometer data format. By extracting the orientation parameters of key locations, an inclinometer dataset that conforms to industry standards and is easy to apply in engineering is generated, providing directly usable measurement results for subsequent drilling operations.

[0119] The technical effect of this solution in this embodiment is that it improves the accuracy and reliability of drilling trajectory determination by establishing a multi-dimensional fitting optimization mechanism. This method first uses weighted fitting technology to generate a preliminary trajectory curve, and then uses a multi-parameter joint diagnosis, including azimuth rate of change, spatial residual, and curvature normal projection, to intelligently identify and classify trajectory fitting points. Differentiated optimization strategies are implemented for different types of fitting points, with a focus on iterative correction of key nodes, ultimately forming a smooth, continuous drilling trajectory that conforms to engineering realities.

[0120] In one possible design, S2046 iteratively optimizes multiple third and fourth fitting points to obtain the second positive drilling trajectory curve, including:

[0121] S20461. Optimize the weights of multiple third fitting points and multiple fourth fitting points to obtain optimized multiple third fitting points and multiple optimized fourth fitting points.

[0122] Specifically, the influence of different fitting points in trajectory calculation can be dynamically adjusted, and weights can be redistributed based on the magnitude of the residuals and the characteristics of azimuth changes at each point. This step is used to assign appropriate influence to problem nodes, so that the optimization process can both correct abnormal segments and maintain the rationality of the overall trajectory. By balancing the contribution of each fitting point, it ensures that the final trajectory curve accurately reflects the measurement data and meets the engineering smoothness requirements.

[0123] S20462. Fit the optimized third fitting points and the optimized fourth fitting points to obtain the third positive drilling trajectory curve.

[0124] Specifically, weighted spline interpolation can be used to reconstruct a continuous spatial curve from the various fitted points after weight adjustment. This step is used to generate a transition trajectory that conforms to actual geological conditions and engineering requirements by considering the optimization weights of different nodes. This allows key sections to be corrected while maintaining a smooth transition of the overall curve, providing an accurate trajectory benchmark for subsequent iterative optimization.

[0125] S20463. Calculate the azimuth rate of change and spatial residual of multiple fitting points on the third positive drilling trajectory curve.

[0126] Specifically, this involves analyzing the azimuth differences and depth variation ratios between adjacent nodes on the optimized trajectory curve, while simultaneously measuring the straight-line distance between the original data points and their corresponding fitted locations. This step evaluates the optimization effect by quantifying the smoothness of the trajectory change and the consistency of the measurement data. It determines whether the current fitting result meets engineering accuracy requirements, providing a quantitative basis for deciding whether to continue iterative optimization and ensuring that the final trajectory both conforms to actual measurements and maintains a reasonable geological orientation trend.

[0127] S20464. Based on the azimuth rate of change and spatial residual of multiple fitting points on the third positive drilling trajectory curve, update multiple third fitting points and multiple fourth fitting points to obtain updated multiple third fitting points and multiple updated multiple fourth fitting points.

[0128] Specifically, based on the abrupt changes in the current trajectory curve and the degree of data consistency, the positions and impact ranges of nodes requiring key optimization can be dynamically adjusted. This step is used to specifically improve sections that have not yet met the standards. By recalibrating the spatial positions and optimization priorities of problem nodes, precise correction targets are provided for the next iteration, gradually achieving overall coordinated optimization of the trajectory curve at sharp bends and smooth sections.

[0129] S20465. The weights of the updated third fitting points and the updated fourth fitting points are optimized multiple times. When the azimuth rate of change of the updated third fitting points is less than the rate of change threshold, or the spatial residual is less than the residual threshold, the updated fourth fitting points are used for fitting to obtain the second positive drilling trajectory curve.

[0130] Specifically, the calculation weight of each node can be adjusted iteratively, gradually reducing its influence weight in sections with sharp turns and large deviations, until the trajectory changes smoothly and meets the standard of consistency with measured data. Then, a second positive drilling trajectory curve is generated based on the stable nodes. This step is used to gradually converge the trajectory characteristics of the problem section to a reasonable range through a gradual correction strategy, ultimately forming a smooth wellbore trajectory that maintains geological steering characteristics while meeting engineering application requirements.

[0131] For example, smooth splines can be used to fit 3D well trajectories. The spline fit should be as close as possible to the original measurement points. However, a certain degree of deviation is allowed to avoid overfitting; the residual at each point is weighted. Adjustment. SX , SY and SZ They are respectively one-dimensional independent variables MD Below NEV The weighted smoothing spline function is used to perform weighted spline fitting for each coordinate component, minimizing the sum of squared weighted residuals. The larger the value, the closer the fitted point is to the 3D well trajectory; the higher the weight. The smaller the value, the further it deviates from the three-dimensional well trajectory. SX , SY and SZ The calculation formula is:

[0132] ,

[0133] in, For the depth of the drilling operation, the measurement point at the magnetic sub section during drilling is... The coordinates were fitted, and the fitted values ​​were obtained as follows:

[0134] ,

[0135] in, , and They are respectively N , E and V The fitted values ​​in three directions are determined by judging whether the change in azimuth angle between adjacent measuring points is less than a user-defined value. Points that deviate from the curve trajectory are marked as a set. :

[0136] ,

[0137] ,

[0138] in, This is the azimuth angle for positive drilling. forN The difference between the fitted values ​​of two adjacent measuring points in the direction. for E The difference between the fitted values ​​of two adjacent measurement points in the direction, whether the angle between the original trajectory direction of a certain measurement point and the spline fitting tangent direction is too large, and whether the residual of that point is also too large. If both conditions are met, it indicates that the point deviates from the overall fitting trend and has an abrupt change in the direction of connection with adjacent points. Points that deviate from the curve trajectory are marked as a set. Calculate the first... i The three-dimensional spatial residuals of each measurement point measure the deviation of that point from the spline fitting position:

[0139] ,

[0140] in, For the first i The residuals at each measuring point, with the median of all residuals being... residual threshold Defined as the median of the residuals plus twice the absolute deviation of the median. :

[0141]

[0142] If a certain point Greater than If the residual at that point is too large, it is considered to be either underfitting or a potential outlier, and further weighting is required.

[0143] Before constructing the fitted curve i Trajectory direction vector of each measuring point The calculation formula is:

[0144]

[0145] The first on the fitted curve i The formula for calculating the tangent vector of the fitted trajectory direction of each measuring point is:

[0146]

[0147] A certain measuring point i The angle between the original trajectory direction and the spline fitting tangent direction is:

[0148] ,

[0149] in To keep the value constant and prevent the denominator from being zero, Given a trend deviation threshold, the set of trend points deviating from the curve trajectory is:

[0150]

[0151] Further eliminate points where the curvature normal deviates from the curve, the first i The first and second derivatives of each measuring point in each direction can be expressed as:

[0152] ,

[0153] in, For the depth of the positive drilling, the fitted spline is in The unit tangent vector at point is:

[0154]

[0155] Fitted splines in The second-order steering at that point is:

[0156]

[0157] The unit normal vector in the direction of curvature is:

[0158]

[0159] No. i The three-dimensional residual vector from each point to the fitted curve is:

[0160]

[0161] The residual vector is in the curvature normal direction The projection in the direction is:

[0162] ,

[0163] ,

[0164] in, for The median absolute deviation is used to determine if a point simultaneously satisfies both "large spatial residual" and "significant deviation from the curvature normal," in which case that point needs to be removed during fitting. The set of all points deviating from the trajectory trend is as follows:

[0165]

[0166] The reference points selected in the first half of the inclinometer data are index Then, the set of points deviating from the trend of the curve trajectory in the latter half of the magnetic ranging data is:

[0167]

[0168] These points are weighted and iterated according to the above steps until there are no markers. The fitting has converged, and the loop exits. The second positive drilling trajectory curve is obtained by fitting the measurement points obtained at the time of loop exit.

[0169] The technical effect of this solution in this embodiment is that it improves the accuracy of drilling trajectory calculation through an intelligent trajectory fitting optimization mechanism. This method first performs fine-grained classification of the fitting points, distinguishing between key control points and ordinary points, and adopts differentiated optimization strategies for different types of points. Then, through multiple rounds of iterative calculation, it dynamically adjusts the weight parameters of each fitting point, making the trajectory curve gradually approximate the actual drilling direction. Finally, it outputs the optimal trajectory when the preset convergence conditions are met. This hierarchical and progressive optimization method effectively overcomes the problem of traditional algorithms being sensitive to abnormal data, ensuring both accurate fitting of key control points and smooth continuity of the overall trajectory curve.

[0170] Figure 3 A flowchart illustrating the method for calculating drilling survey data provided in the embodiments of this application. Figure 2 In this embodiment, in Figure 2 Based on the provided embodiments, the calculation method for drilling directional measurement data is further explained. The calculation method for drilling directional measurement data includes:

[0171] S301. Acquire multiple first inclination measurement data, multiple second inclination measurement data, and multiple magnetic distance measurement data; wherein, the multiple first inclination measurement data refers to the inclination measurement data of the drilled portion of the well being drilled, the multiple second inclination measurement data refers to the inclination measurement data of the drilled well, and the multiple magnetic distance measurement data is used to represent the relative distance between the magnetic sub in the well being drilled and the probe in the drilled well.

[0172] S302. Perform coordinate transformation on multiple second inclination data to obtain multiple first coordinates; among them, the multiple first coordinates are used to represent the spatial trajectory of the drilled well.

[0173] S303. Based on multiple magnetic ranging data, the coordinates of multiple first coordinates are corrected to obtain multiple second coordinates; wherein, the multiple second coordinates are used to represent the spatial trajectory of the subsequent drilling section of the well.

[0174] S304. Fit multiple first inclination measurement data and multiple second coordinates to obtain multiple third inclination measurement data; where the multiple third inclination measurement data refer to the inclination measurement data of the well in progress.

[0175] S301-S304 are similar to S201-S204, and will not be described again in this embodiment.

[0176] S305. Calculate the minimum distance between multiple second inclinometer data and multiple third inclinometer data.

[0177] Specifically, based on the principle of spatial geometric projection, the perpendicular relationship between the measuring point and the fitted trajectory can be established through vector cross product, and the shortest perpendicular distance from each measuring point to the trajectory curve can be selected as the minimum distance. This step is used to detect the deviation between the actual drilling trajectory and the design model in real time. When abnormal deviation is detected, a deviation correction mechanism is triggered to ensure that the wellbore trajectory is always within the safe range allowed by the geological target.

[0178] S306. When the minimum distance is less than the preset safety threshold, input multiple third inclinometer data into the preset trajectory adjustment model to obtain the trajectory adjustment scheme.

[0179] Specifically, when insufficient spacing between two well trajectories is detected, the problematic trajectory parameters can be imported into a pre-established anti-collision optimization algorithm. By analyzing current geological conditions and drilling parameters, a solution including trajectory correction direction and magnitude is generated. This step is used to automatically handle potential wellbore collision problems, providing on-site engineers with timely and reliable adjustment basis through intelligent trajectory optimization suggestions, ensuring the safety of subsequent drilling processes and the accuracy of trajectory control.

[0180] The technical effect of this solution in this embodiment is that it effectively ensures the safety of drilling operations through an intelligent anti-collision early warning mechanism. This method calculates the minimum distance between the new drilling trajectory and the trajectory of adjacent wells in real time, and automatically triggers a trajectory adjustment model to generate an avoidance plan when a potential collision problem is detected. This proactive defense mechanism realizes a shift from passive detection to proactive prevention, not only promptly detecting potential wellbore collision hazards but also providing scientific trajectory correction suggestions to avoid collision problems during the drilling process.

[0181] Figure 4 A schematic diagram of the structure of the drilling survey data calculation device provided in the embodiments of this application. Figure 4 As shown, the device for calculating the drilling survey data includes:

[0182] The acquisition module 401 is used to acquire multiple first inclination measurement data, multiple second inclination measurement data, and multiple magnetic distance measurement data; wherein, the multiple first inclination measurement data refers to the inclination measurement data of the drilled part of the well being drilled, the multiple second inclination measurement data refers to the inclination measurement data of the drilled well, and the multiple magnetic distance measurement data is used to represent the relative distance between the magnetic sub in the well being drilled and the probe in the drilled well.

[0183] The coordinate transformation module 402 is used to transform multiple second inclination data to obtain multiple first coordinates; wherein the multiple first coordinates are used to represent the spatial trajectory of the drilled well.

[0184] The coordinate correction module 403 is used to correct multiple first coordinates based on multiple magnetic ranging data to obtain multiple second coordinates; wherein the multiple second coordinates are used to represent the spatial trajectory of the subsequent drilling section of the well.

[0185] The fitting module 404 is used to fit multiple first inclination data and multiple second coordinates to obtain multiple third inclination data; wherein, the multiple third inclination data refers to the inclination data of the well in progress.

[0186] In one possible implementation, the coordinate transformation module 402 includes:

[0187] The first acquisition unit is used to acquire the wellhead coordinates of the drilled well; wherein, the wellhead coordinates of the drilled well refer to the coordinates of the wellhead in the first coordinate system, and the first coordinate system refers to the global coordinate system established with the preset measurement reference point as the origin.

[0188] The coordinate transformation unit is used to transform multiple second inclination data to obtain multiple third coordinates. Among them, the multiple third coordinates are the coordinates of the drilled well trajectory in the second coordinate system. The second coordinate system refers to the local coordinate system established with the wellhead coordinates of the drilled well as the coordinate origin.

[0189] The coordinate correction unit is used to correct multiple third coordinates based on the wellhead coordinates of the drilled well to obtain multiple first coordinates.

[0190] In one possible implementation, the coordinate correction module 403 includes:

[0191] The position calculation unit is used to calculate the position based on multiple magnetic ranging data to obtain the positions of multiple probe measuring points; where the multiple probe measuring point positions refer to the positions of the probe in the drilled well when magnetic ranging measurements are performed.

[0192] Angle calculation unit is used to calculate angles based on the positions of multiple probe measuring points to obtain multiple azimuth angles; among which, multiple azimuth angles are used to represent the extension direction of the drilled well at the multiple probe measuring point positions.

[0193] The offset calculation unit is used to calculate the spatial offset based on multiple magnetic ranging data and multiple azimuth angles. The spatial offset is used to represent the relative displacement between multiple probe measuring points and multiple drilling target points. The multiple drilling target points refer to the trajectory points on the subsequent drilling section of the drilling process.

[0194] The vector overlay unit is used to overlay multiple probe measurement points and spatial offsets to obtain multiple second coordinates; among them, the multiple second coordinates are the coordinates of multiple positive drilling target points in the global coordinate system.

[0195] In one possible implementation, the fitting module 404 includes:

[0196] The fitting unit is used to fit multiple first inclination measurement data and multiple second coordinates according to multiple preset weights to obtain a first positive drilling trajectory curve; wherein the first positive drilling trajectory curve includes multiple first fitting points.

[0197] The first calculation unit is used to calculate the azimuth change rate corresponding to each first fitting point; wherein, the azimuth change rate is used to represent the degree of azimuth change between each first fitting point and its adjacent first fitting points.

[0198] The second calculation unit is used to calculate the spatial residual between multiple original data points and multiple first fitting points; wherein, the multiple original data points include multiple first inclinometer data and multiple second coordinates, and the spatial residual is used to represent the deviation between the multiple original data points and the multiple first fitting points.

[0199] The third calculation unit is used to calculate the curvature normal projection of the first positive drilling trajectory curve at multiple first fitting points; wherein, the curvature normal projection is used to represent the degree to which each original data point deviates from the first positive drilling trajectory curve.

[0200] A classification unit is used to classify multiple first fitting points to obtain multiple second fitting points, multiple third fitting points, and multiple fourth fitting points. Among them, multiple second fitting points refer to first fitting points whose spatial residuals are greater than a preset residual threshold and whose curvature normal projections are greater than a preset projection threshold; multiple third fitting points refer to first fitting points whose azimuth rate of change is greater than a preset rate of change threshold or whose spatial residuals are greater than a residual threshold; and multiple fourth fitting points refer to fitting points other than multiple second and multiple third fitting points among multiple first fitting points.

[0201] The optimization unit is used to iteratively optimize multiple third fitting points and multiple fourth fitting points to obtain the second positive drilling trajectory curve.

[0202] The sampling unit is used to sample and calculate the second positive drilling trajectory curve to obtain multiple third inclination measurement data.

[0203] In one possible implementation, the optimization unit includes:

[0204] The first optimization component is used to optimize the weights of multiple third fitting points and multiple fourth fitting points to obtain optimized multiple third fitting points and multiple optimized fourth fitting points.

[0205] The fitting component is used to fit multiple optimized third fitting points and multiple optimized fourth fitting points to obtain the third positive drilling trajectory curve.

[0206] The first calculation component is used to calculate the azimuth rate of change and spatial residual of multiple fitted points on the third positive drilling trajectory curve.

[0207] An update component is used to update multiple third and fourth fitting points based on the azimuth change rate and spatial residual of multiple fitting points on the third positive drilling trajectory curve, resulting in updated third and fourth fitting points.

[0208] The second optimization component is used to optimize the weights of the updated third fitting points and the updated fourth fitting points multiple times. When the azimuth rate of change of the updated third fitting points is less than the rate of change threshold, or the spatial residual is less than the residual threshold, the updated fourth fitting points are used for fitting to obtain the second positive drilling trajectory curve.

[0209] In one possible implementation, the drilling survey data calculation device further includes:

[0210] The distance calculation module is used to calculate the minimum distance between multiple second inclinometer data and multiple third inclinometer data.

[0211] The scheme determination module is used to input multiple third inclinometer data into a preset trajectory adjustment model to obtain a trajectory adjustment scheme when the minimum distance is less than a preset safety threshold.

[0212] The drilling directional measurement data calculation device provided in this embodiment can execute... Figure 2 and Figure 3 The technical solution of the embodiment of the drilling survey data calculation method shown herein, its implementation principle and technical effect are similar to Figure 2 and Figure 3 The implementation method for calculating drilling survey data shown is similar and will not be described in detail here.

[0213] Figure 5 This is a schematic diagram of the hardware structure of the electronic device provided in an embodiment of this application. Figure 5 As shown, the electronic device 50 includes at least one processor 510 and a memory 520. The electronic device also includes a communication component 530. The processor 510, memory 520, and communication component 530 are connected via a bus 540.

[0214] In the specific implementation process, at least one processor 510 executes computer execution instructions stored in memory 520, so that at least one processor 510 is used to implement a method for calculating drilling survey data in the above embodiment.

[0215] The specific implementation process of processor 510 can be found in the above method embodiments, and its implementation principle and technical effect are similar. It will not be repeated here.

[0216] In the above embodiments, it should be understood that the processor 510 can be a Central Processing Unit (CPU), or other general-purpose processors, digital signal processors (DSPs), application-specific integrated circuits (ASICs), etc. The general-purpose processor can be a microprocessor or any conventional processor. The steps of the method disclosed in this invention can be directly implemented by a hardware processor, or implemented by a combination of hardware and software modules within the processor.

[0217] The memory 520 may include high-speed RAM memory, and may also include non-volatile memory NVM, such as at least one disk storage.

[0218] Bus 540 can be an Industry Standard Architecture (ISA) bus, a Peripheral Component Interconnect (PCI) bus, or an Extended Industry Standard Architecture (EISA) bus, etc. Bus 540 can be divided into address bus, data bus, control bus, etc. For ease of illustration, the bus 540 in the accompanying drawings of this application is not limited to only one bus or one type of bus.

[0219] The above description of the functions implemented by electronic devices and main control devices has introduced the solutions provided by the embodiments of the present invention. It is understood that, in order to implement the above functions, the electronic device or main control device includes hardware structures and / or software modules corresponding to the execution of each function. By combining the units and algorithm steps of the various examples described in the embodiments of the present invention, the embodiments of the present invention can be implemented in hardware or a combination of hardware and computer software. Whether a function is executed by hardware or by computer software driving hardware depends on the specific application and design constraints of the technical solution. Those skilled in the art can use different methods to implement the described functions for each specific application, but such implementation should not be considered beyond the scope of the technical solutions of the embodiments of the present invention.

[0220] This application also provides a computer-readable storage medium storing computer-executable instructions. When executed by a processor, these instructions are used to implement a method for calculating drilling directional measurement data as described in the above embodiments. In the specific implementation of the aforementioned method for calculating drilling directional measurement data, each module can be implemented as a processor.

[0221] The aforementioned readable storage medium can be implemented by any type of volatile or non-volatile storage device or a combination thereof, such as static random access memory (SRAM), electrically erasable programmable read-only memory (EEPROM), erasable programmable read-only memory (EPROM), programmable read-only memory (PROM), read-only memory (ROM), magnetic storage, flash memory, magnetic disk, or optical disk. The readable storage medium can be any available medium accessible to a general-purpose or special-purpose computer.

[0222] An exemplary readable storage medium is coupled to a processor, enabling the processor to read information from and write information to the readable storage medium. Of course, the readable storage medium can also be a component of the processor. The processor and the readable storage medium can reside in application-specific integrated circuits (ASICs). Alternatively, the processor and the readable storage medium can exist as discrete components in an electronic device or a host device.

[0223] This application also provides a computer program product, including a computer program, which, when executed by a processor, is used to implement a method for calculating drilling survey data as described in the above embodiments.

[0224] The computer program is stored in a readable storage medium, and at least one processor can read the computer program from the readable storage medium and execute the computer program to perform the scheme provided in any of the above embodiments.

[0225] Those skilled in the art will understand that all or part of the steps of the above method embodiments can be implemented by hardware related to program instructions. The aforementioned program can be stored in a computer-readable storage medium. When the program is executed, it performs the steps of the above method embodiments; and the aforementioned storage medium includes various media capable of storing program code, such as ROM, RAM, magnetic disk, or optical disk.

[0226] The technical solutions of this application have been described above with reference to the preferred embodiments shown in the accompanying drawings. However, it is readily understood by those skilled in the art that the scope of protection of this application is obviously not limited to these specific embodiments. The above embodiments are only used to illustrate the technical solutions of this application and are not intended to limit them. Although this application has been described in detail with reference to the foregoing embodiments, those skilled in the art should understand that modifications can still be made to the technical solutions described in the foregoing embodiments, or equivalent substitutions can be made to some or all of the technical features therein. These modifications or substitutions do not cause the essence of the corresponding technical solutions to deviate from the scope of the technical solutions of the embodiments of this application.

Claims

1. A method of calculating wellbore survey data, characterized by, The method comprises the following steps: S1. obtaining first inclination data, second inclination data and magnetic ranging data; wherein the first inclination data refers to inclination data of a drilled part of a current well, the second inclination data refers to inclination data of a drilled well, and the magnetic ranging data is used to represent the relative distance between a magnetic sub in the current well and a probe pipe in the drilled well; S2. performing coordinate conversion on the second inclination data to obtain first coordinates; wherein the first coordinates are used to represent the spatial trajectory of the drilled well; S3. performing coordinate correction on the first coordinates according to the magnetic ranging data to obtain second coordinates; wherein the second coordinates are used to represent the spatial trajectory of a subsequent drilling section of the current well; S4. fitting the first inclination data and the second coordinates to obtain third inclination data; wherein the third inclination data refers to the inclination data of the current well; The S4 comprises: fitting the first inclination data and the second coordinates according to a preset weight to obtain a first current well trajectory curve; wherein the first current well trajectory curve comprises first fitting points; calculating the azimuth angle change rate corresponding to each first fitting point; wherein the azimuth angle change rate is used to represent the azimuth angle change degree between each first fitting point and an adjacent first fitting point; calculating the spatial residual between original data points and the first fitting points; wherein the original data points comprise the first inclination data and the second coordinates, and the spatial residual is used to represent the deviation between the original data points and the first fitting points; calculating the curvature normal projection of the first current well trajectory curve at the first fitting points; wherein the curvature normal projection is used to represent the degree of deviation of each original data point from the first current well trajectory curve; classifying the first fitting points to obtain second fitting points, third fitting points and fourth fitting points; wherein the second fitting points refer to the first fitting points with the spatial residual greater than a preset residual threshold and the curvature normal projection greater than a preset projection threshold, the third fitting points refer to the first fitting points with the azimuth angle change rate greater than a preset change rate threshold or the spatial residual greater than the residual threshold, and the fourth fitting points refer to the fitting points in the first fitting points other than the second fitting points and the third fitting points; performing iterative optimization on the third fitting points and the fourth fitting points to obtain a second current well trajectory curve; sampling and calculating the second current well trajectory curve to obtain the third inclination data.

2. The method of calculating well survey data according to claim 1, wherein, The S2 comprises: obtaining the wellhead coordinates of the drilled well; wherein the wellhead coordinates of the drilled well refer to the coordinates of the wellhead of the drilled well in a first coordinate system, and the first coordinate system refers to a global coordinate system established with a preset measurement reference point as the coordinate origin; performing coordinate conversion on the second inclination data to obtain third coordinates; wherein the third coordinates are the coordinates of the trajectory of the drilled well in a second coordinate system, and the second coordinate system refers to a local coordinate system established with the wellhead coordinates of the drilled well as the coordinate origin; The third coordinate is corrected according to the wellhead coordinate of the drilled well, and the first coordinate is obtained.

3. The method of calculating well survey data according to claim 2, wherein, The S3 comprises: A position is calculated according to the magnetic ranging data, and a probe measuring point position is obtained; wherein the probe measuring point position refers to the position of the probe in the drilled well when the magnetic ranging measurement is performed; An angle is calculated according to the probe measuring point position, and an azimuth angle is obtained; wherein the azimuth angle is used to represent the extension direction of the drilled well at the probe measuring point position; A spatial offset is calculated according to the magnetic ranging data and the azimuth angle; wherein the spatial offset is used to represent the relative displacement between the probe measuring point position and a positive drilling target point, and the positive drilling target point refers to a track point on a subsequent drilling section of the positive drilling well; The second coordinate is obtained by vector superposition according to the probe measuring point position and the spatial offset; wherein the second coordinate is the coordinate of the positive drilling target point in the global coordinate system.

4. The method of calculating well survey data according to claim 1, wherein, The third fitting point and the fourth fitting point are iteratively optimized to obtain a second positive drilling trajectory curve, comprising: The weights of the third fitting point and the fourth fitting point are optimized to obtain an optimized third fitting point and an optimized fourth fitting point; The third positive drilling trajectory curve is obtained by fitting according to the optimized third fitting point and the optimized fourth fitting point; The azimuth angle change rate and the spatial residual of the fitting point on the third positive drilling trajectory curve are calculated; The third fitting point and the fourth fitting point are updated according to the azimuth angle change rate and the spatial residual of the fitting point on the third positive drilling trajectory curve to obtain an updated third fitting point and an updated fourth fitting point; The weights of the updated third fitting point and the updated fourth fitting point are optimized for multiple times, and when the azimuth angle change rate of the updated third fitting point is less than the change rate threshold value or the spatial residual is less than the residual threshold value, the second positive drilling trajectory curve is obtained by fitting according to the updated fourth fitting point.

5. The method of calculating well survey data according to claim 1, wherein, After the first inclination data and the second coordinate are fitted to obtain the third inclination data, the method further comprises: The minimum distance between the second inclination data and the third inclination data is calculated; When the minimum distance is less than a preset safety threshold, the third inclination data is input into a preset trajectory adjustment model to obtain a trajectory adjustment scheme.

6. A computing device for drilling inclination data, characterized by Comprises: An acquisition module is configured to acquire first inclination data, second inclination data and magnetic ranging data; wherein the first inclination data refers to the inclination data of the drilled part of the positive drilling well, the second inclination data refers to the inclination data of the drilled well, and the magnetic ranging data is used to represent the relative distance between the magnetic sub in the positive drilling well and the probe in the drilled well; A coordinate conversion module is configured to convert the coordinates of the second inclination data to obtain first coordinates; wherein the first coordinates are used to represent the spatial trajectory of the drilled well; A coordinate correction module is configured to correct the first coordinates according to the magnetic ranging data to obtain second coordinates; wherein the second coordinates are used to represent the spatial trajectory of the subsequent drilling section of the positive drilling well. a fitting module configured to fit the first inclination data and the second coordinates to obtain third inclination data, wherein the third inclination data refers to the inclination data of the drilling well; fit the first inclination data and the second coordinates according to a preset weight to obtain a first drilling well trajectory curve, wherein the first drilling well trajectory curve comprises first fitting points; calculate an azimuth rate of change corresponding to each of the first fitting points, wherein the azimuth rate of change is used to represent a degree of change in azimuth angle between each of the first fitting points and an adjacent first fitting point; calculate a spatial residual between an original data point and the first fitting point, wherein the original data point comprises the first inclination data and the second coordinates, and the spatial residual is used to represent a deviation between the original data point and the first fitting point; calculate a curvature normal projection of the first drilling well trajectory curve at the first fitting point, wherein the curvature normal projection is used to represent a degree of deviation of each of the original data points from the first drilling well trajectory curve; classify the first fitting points to obtain second fitting points, third fitting points and fourth fitting points, wherein the second fitting points refer to the first fitting points with a spatial residual greater than a preset residual threshold and a curvature normal projection greater than a preset projection threshold, the third fitting points refer to the first fitting points with an azimuth rate of change greater than a preset change rate threshold or a spatial residual greater than the residual threshold, and the fourth fitting points refer to the first fitting points other than the second fitting points and the third fitting points; perform iterative optimization on the third fitting points and the fourth fitting points to obtain a second drilling well trajectory curve; perform sampling calculation on the second drilling well trajectory curve to obtain the third inclination data.

7. An electronic device, comprising: comprise: a processor, and a memory connected to the processor in communication; the memory stores computer-executable instructions; when the processor executes the computer-executable instructions stored in the memory, the processor is configured to implement the method for calculating drilling inclination data according to any one of claims 1 to 5.

8. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores computer-executable instructions, and when the processor executes the computer-executable instructions, the computer-readable storage medium is configured to implement the method for calculating drilling inclination data according to any one of claims 1 to 5.

9. A computer program product, characterised in that, The computer program is configured to implement the method for calculating drilling inclination data according to any one of claims 1 to 5 when the processor executes the computer program.

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