Fracturing deployment optimization method and electronic device

Abstract

The embodiment of the application provides a fracturing implementation deployment optimization method and an electronic device, and relates to the technical field of fracturing reconstruction. The method comprises the following steps: performing spatial division according to a borehole trajectory of a region to be analyzed and preset reconstruction information, and obtaining a plurality of sub-regions to be analyzed; obtaining a first coordinate of a model grid unit based on a three-dimensional reservoir sweet spot distribution model that has been constructed, and mapping the first coordinate to a current borehole local coordinate system by using a preset coordinate conversion algorithm to obtain a second coordinate of the model grid unit; obtaining a sweet spot index set corresponding to a current sub-region to be analyzed by position screening; and outputting fracturing implementation deployment information according to a plurality of sweet spot index sets corresponding to the region to be analyzed. By combining the borehole trajectory and the preset reconstruction information, the fracturing influence range is divided, and the three-dimensional reservoir sweet spot distribution model is mapped to the borehole local coordinate system, so that the analysis and effective identification of the recoverable potential of the far-well region fracturing are realized, and the accuracy of fracturing deployment is improved.

Description

Fracturing Implementation Deployment Optimization Methods and Electronic Equipment Technical Field

[0001] This application relates to the field of fracturing technology, and in particular to a method for optimizing fracturing implementation and deployment, and an electronic device. Background Technology

[0002] In the development of unconventional oil and gas reservoirs, the wellbore trajectory, as the basic path for horizontal well drilling and fracturing operations, not only determines the spatial range of the reservoir traversed by the wellbore but also serves as a spatial reference axis for subsequent reservoir analysis and fracturing deployment. Due to the generally low permeability, underdeveloped fractures, and high fracturing difficulty of unconventional reservoirs, multi-stage fracturing and multi-cluster perforation methods are necessary for effective reservoir stimulation. However, the reservoir itself is typically heterogeneous, with drastic variations in formation properties, resulting in a limited spatial distribution of truly high-production potential "sweet spots." To improve fracturing effectiveness and reduce the risk of ineffective stimulation, the sweet spot index of the reservoir is used as an important indicator of its potential for stimulation. The analysis results of the sweet spot index are used to determine the locations of fracturing stages and perforations, thereby improving the rate of return on production and resource utilization efficiency.

[0003] In existing technologies, the sweet spot index is primarily obtained based on the interpretation results of well logging curves. This method generates a sweet spot index interpretation curve along the depth direction of the wellbore by analyzing well logging parameters such as porosity, permeability, brittleness, and oil saturation in the region adjacent to the wellbore trajectory. This interpretation curve is used as the basis for dividing the fracturing section and setting the location of perforation clusters. In actual deployment, operators typically select well sections with higher sweet spot indices as fracturing sections and arrange perforation clusters within these sections to guide fracture propagation into the sweet spot area and improve the stimulation effect.

[0004] It is evident that current fracturing deployment information is primarily determined based on the sweet spot distribution in the vicinity of the wellbore, failing to consider the spatial heterogeneity of the reservoir within the fracturing area. Specifically, the sweet spot distribution near the wellbore often differs from that far from the wellbore, leading to a mismatch between the identified fracturing sections and perforation cluster locations and the actual high-yield areas, thus limiting fracturing effectiveness. Therefore, an optimized fracturing deployment method is urgently needed to address the technical problem of inaccurate fracturing deployment information. Summary of the Invention

[0005] This application provides a fracturing deployment optimization method and electronic device to comprehensively identify the distribution of sweet spots within the fracturing modification range, thereby improving the accuracy of fracturing deployment information.

[0006] In a first aspect, embodiments of this application provide a method for optimizing fracturing deployment, including:

[0007] Based on the wellbore trajectory of the area to be analyzed and the preset modification information corresponding to the wellbore trajectory, the area to be analyzed is spatially divided to obtain multiple sub-areas to be analyzed.

[0008] Based on the trajectory sub-segment corresponding to the current sub-region to be analyzed, obtain the current local coordinate system of the wellbore corresponding to the trajectory sub-segment;

[0009] Based on the constructed three-dimensional reservoir sweet spot distribution model, the first coordinates of multiple model grid cells in the region to be analyzed are obtained in the geodetic coordinate system, and the first coordinates are mapped to the local coordinate system of the current wellbore through a preset coordinate transformation algorithm to obtain the second coordinates of multiple model grid cells.

[0010] Based on the second coordinates of the model grid cell, when it is determined that the model grid cell is located in the current sub-region to be analyzed, the sweetness index of the model grid cell is obtained to obtain the sweetness index set corresponding to the current sub-region to be analyzed;

[0011] Based on the sweetness index set corresponding to multiple sub-regions to be analyzed, output the fracturing implementation deployment information of the sub-regions to be analyzed.

[0012] In one possible implementation, the step of spatially dividing the region to be analyzed based on the wellbore trajectory of the region to be analyzed and the preset modification information corresponding to the wellbore trajectory to obtain multiple sub-regions to be analyzed includes:

[0013] Obtain the three-dimensional trajectory information of the wellbore trajectory, and determine the continuous coordinate point sequence of the wellbore trajectory along the depth measurement direction based on the three-dimensional trajectory information;

[0014] Obtain one or more local coordinate systems corresponding to the wellbore trajectory, and based on the local coordinate systems, divide the continuous coordinate point sequence according to the modification width in the preset modification information to obtain multiple trajectory segments;

[0015] Based on the preset modification information, the modification length and modification height are obtained, as well as the propagation direction of the fracturing crack corresponding to the modification length;

[0016] Based on the modified length, the direction of fracturing crack propagation, and the modified height, by setting the trajectory segment as the central axis, a sub-region to be analyzed corresponding to the trajectory segment is constructed to obtain multiple sub-regions to be analyzed.

[0017] In one possible implementation, based on the wellbore local coordinate system, and according to the modification width in the preset modification information, the continuous coordinate point sequence is divided into equally spaced segments to obtain multiple trajectory sub-segments, including:

[0018] Multiple consecutive coordinate points belonging to the same wellbore local coordinate system are selected and obtained. Based on the modification width, the multiple consecutive coordinate points are divided into equal intervals to obtain one or more trajectory sub-segments corresponding to the wellbore local coordinate system.

[0019] Traverse multiple wellbore local coordinate systems to obtain one or more trajectory segments corresponding to each wellbore local coordinate system, thereby obtaining multiple trajectory segments.

[0020] In one possible implementation, obtaining the first coordinates of multiple model grid cells in the geodetic coordinate system based on the constructed three-dimensional reservoir sweet spot distribution model includes:

[0021] Obtain the constructed three-dimensional reservoir sweet spot distribution model; wherein the three-dimensional reservoir sweet spot distribution model is composed of multiple model grid cells, and each model grid cell has a unique spatial index and attribute parameters;

[0022] Multiple model grid cells located within the area to be analyzed are selected, and the center point coordinates of the model grid cells in the geodetic coordinate system are extracted. The center point coordinates are used as the first coordinates of the model grid cells.

[0023] In one possible implementation, the step of mapping the first coordinates to the current wellbore local coordinate system using a preset coordinate transformation algorithm to obtain the second coordinates of the multiple model mesh elements includes:

[0024] The coordinates of the origin of the current wellbore local coordinate system in the geodetic coordinate system are recorded as the coordinates of the reference point; wherein, the geodetic coordinate system and the current wellbore local coordinate system are a common Z-axis coordinate system;

[0025] Based on the geodetic coordinate system and the current wellbore local coordinate system, obtain the horizontal azimuth rotation angle of the geodetic coordinate system and the current wellbore local coordinate system;

[0026] Based on the first coordinates of the model grid cell, the coordinates of the reference point, and the horizontal azimuth rotation angle, the first coordinates are mapped to the current wellbore local coordinate system to obtain the second coordinates of multiple model grid cells.

[0027] In one possible implementation, the step of mapping the first coordinates to the current wellbore local coordinate system based on the first coordinates of the model grid cells, the coordinates of the reference point, and the horizontal azimuth rotation angle, to obtain the second coordinates of multiple model grid cells includes:

[0028] Based on the first coordinate (x) of the model mesh element p y p , zp The coordinates of the reference point and the horizontal azimuth rotation angle are determined using the following formula:

[0029]

[0030] Calculate and obtain the second coordinate (x') of the model mesh element. p y' p , z' p );in, and θ represents the x-coordinate and y-coordinate of the reference point, respectively; θ is the horizontal azimuth rotation angle.

[0031] In one possible implementation, determining that the model mesh cell is located in the current sub-region to be analyzed based on the second coordinates of the model mesh cell includes:

[0032] When the angle between the direction of the fracturing fracture and the trajectory segment is 90°, if the second coordinate (x') of the model mesh element... p y' p , z' p Satisfies the formula:

[0033]

[0034] Then it is determined that the model mesh element is located in the current sub-region to be analyzed;

[0035] Among them, L w To modify the width, L f H represents the length of the modification, and H represents the height of the modification; z w The left endpoint of the trajectory segment is the vertical coordinate of the left endpoint of the trajectory segment, and the left endpoint of the trajectory segment is the endpoint closest to the origin of the local coordinate system of the wellbore.

[0036] In one possible implementation, determining that the model mesh cell is located in the current sub-region to be analyzed based on the second coordinates of the model mesh cell further includes:

[0037] When the angle between the fracturing fracture propagation direction and the wellbore is less than 90°, if the second coordinate (x') of the model mesh element... p y' p , z' p Satisfies the formula:

[0038] or,

[0039] or,

[0040]

[0041] Then it is determined that the model mesh element is located in the current sub-region to be analyzed;

[0042] Among them, L w To modify the width, L f H represents the length of the modification, and H represents the height of the modification; z w β is the vertical coordinate of the left endpoint of the trajectory segment, and the left endpoint of the trajectory segment is the endpoint closest to the origin of the local coordinate system of the wellbore, and β is the angle between the direction of the fracturing fracture propagation and the wellbore.

[0043] In one possible implementation, based on the sweet spot index set corresponding to multiple sub-regions to be analyzed, fracturing deployment information for the regions to be analyzed is output, including:

[0044] Based on one or more dessert indices from the dessert index set, the comprehensive dessert value for each sub-region to be analyzed is calculated by summing them.

[0045] If the overall sweetness value is greater than or equal to the sweetness threshold, the sub-region to be analyzed is recorded as a priority fracturing segment, and fracturing implementation deployment information carrying the priority fracturing segment and the uniformly deployed perforation cluster of the priority fracturing segment is output.

[0046] Secondly, embodiments of this application provide an apparatus for optimizing fracturing deployment information, comprising:

[0047] The region division module is used to spatially divide the region to be analyzed based on the well trajectory of the region to be analyzed and the preset modification information corresponding to the well trajectory, and obtain multiple sub-regions to be analyzed.

[0048] The coordinate system acquisition module is used to acquire the current local coordinate system of the wellbore corresponding to the trajectory segment corresponding to the current sub-region to be analyzed;

[0049] The coordinate mapping module is used to obtain the first coordinates of multiple model grid cells in the geodetic coordinate system in the area to be analyzed based on the constructed three-dimensional reservoir sweet spot distribution model, and to map the first coordinates to the local coordinate system of the current wellbore through a preset coordinate transformation algorithm to obtain the second coordinates of the multiple model grid cells.

[0050] The dessert index acquisition module is used to acquire the dessert index of the model grid cell based on the second coordinate of the model grid cell when it is determined that the model grid cell is located in the current sub-region to be analyzed, so as to obtain the dessert index set corresponding to the current sub-region to be analyzed;

[0051] The deployment information output module is used to output fracturing implementation deployment information for the region to be analyzed based on the sweet spot index set corresponding to the multiple sub-regions to be analyzed.

[0052] Thirdly, embodiments of this application provide an electronic device, including: a memory and a processor;

[0053] The memory stores computer-executed instructions;

[0054] The processor executes computer execution instructions stored in the memory, causing the processor to perform the first aspect and / or various possible implementations of the first aspect as described above.

[0055] Fourthly, embodiments of this application provide a computer-readable storage medium storing computer-executable instructions, which, when executed by a processor, are used to implement the first aspect and / or various possible implementations of the first aspect.

[0056] Fifthly, embodiments of this application provide a computer program product, including a computer program that, when executed by a processor, implements the first aspect and / or various possible implementations of the first aspect.

[0057] This application provides a fracturing deployment optimization method and electronic device. By spatially dividing the area to be analyzed based on the wellbore trajectory and corresponding preset stimulation information, and further obtaining multiple sub-regions, it achieves accurate segmentation of the reservoir space, making the analysis range more closely match the volume area potentially affected by fracturing fractures, ensuring the subsequent analysis has engineering relevance. By obtaining the trajectory segment corresponding to the current sub-region and establishing a local coordinate system based on this trajectory segment, coordinate transformation has a unified directional reference, achieving accurate spatial mapping and improving the accuracy of the spatial correspondence between model grid units and trajectories. Combined with the constructed three-dimensional reservoir sweet spot distribution model, it obtains the first coordinates of multiple model grid units in the geodetic coordinate system and converts them to the second coordinates in the current wellbore local coordinate system using a preset coordinate transformation algorithm. Based on the second coordinates, it performs spatial filtering of model grid units and extracts the sweet spot index of the grids located within the current sub-region to be analyzed, achieving focused analysis of the reservoir quality in the locally stimulated area. Finally, by aggregating the sweet spot index sets of multiple sub-regions to be analyzed, the fracturing implementation deployment information of the entire region to be analyzed can be determined, which helps to improve the accuracy and rationality of fracturing segment division and perforation deployment, thereby enhancing the actual transformation efficiency and production capacity potential of fracturing operations. Attached Figure Description

[0058] 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.

[0059] Figure 1 is a schematic diagram of the fracturing modification scenario provided in this application;

[0060] Figure 2 is a flowchart illustrating the fracturing implementation deployment optimization method provided in an embodiment of this application;

[0061] Figure 3 is a schematic flowchart of a method for obtaining multiple sub-regions to be analyzed provided in an embodiment of this application;

[0062] Figure 4 is a schematic diagram of the planar structure of the region to be analyzed provided in an embodiment of this application;

[0063] Figure 5 is a three-dimensional structural diagram of the division of the sub-region to be analyzed provided in an embodiment of this application;

[0064] Figure 6 is a schematic flowchart of the method for obtaining the second coordinates of a model mesh element provided in an embodiment of this application;

[0065] Figure 7 is a schematic diagram of the coordinate transformation provided in the embodiment of this application;

[0066] Figure 8 is a schematic diagram of two-dimensional coordinate transformation in different coordinate systems provided in the embodiments of this application;

[0067] Figure 9 is a schematic diagram showing the comparative analysis results of the implementation cases provided in the embodiments of this application;

[0068] Figure 10 is a schematic diagram of the optimization device provided in this application;

[0069] Figure 11 is a schematic diagram of the structure of the electronic device provided in this application.

[0070] 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

[0071] 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.

[0072] First, let me explain the terms used in this application:

[0073] Fracturing stimulation range: refers to the three-dimensional spatial area in the reservoir where fractures can actually extend, act, and produce stimulation effects during the fracturing operation;

[0074] Wellbore trajectory: refers to the actual path of the wellbore formed in three-dimensional space during the drilling process, which consists of a series of continuous spatial coordinate points;

[0075] Local coordinate system of wellbore: It is a local reference coordinate system established with a small segment of the wellbore trajectory as the center. Its coordinate axes are usually parallel to the strike of the well segment. It is used to simplify the judgment of spatial position and coordinate transformation during fracturing analysis.

[0076] Three-dimensional reservoir sweet spot distribution model: a three-dimensional numerical model constructed through geological modeling, in which each model grid cell carries a sweet spot index describing reservoir quality, used to characterize the spatial distribution of high-yield potential areas;

[0077] Sweet spot index: This is an index used to comprehensively evaluate the reservoir characteristics of a single grid cell. Its calculation basis may include multiple reservoir parameters such as porosity, permeability, organic matter abundance, brittleness index, and stress conditions.

[0078] Figure 1 is a schematic diagram of the fracturing stimulation scenario provided in this application. In existing industrial practice, the division of fracturing sections and the determination of perforation locations usually rely on the sweet spot index curve obtained from well logging interpretation. This curve reflects the trend of geological attribute changes in the vicinity of the wellbore. As shown in Figure 1, the sweet spot distribution generally refers to the area within a few meters on both sides of the wellbore, corresponding only to the "near-wellbore range" (the red area in position 1 and the gray area in position 2 in the figure). However, the fracturing stimulation range not only includes the near-wellbore range but also the more distant wellbore area as the fracturing fractures extend. In position 1 (shown in the upper half of the figure), although the fracturing fracture is located in the sweet spot area at the initial stage of fracturing, as the fracture extends further away from the wellbore, the fracturing fracture may touch low-quality or non-sweet spot areas in the reservoir (the gray area in the figure), resulting in wasted fracturing energy and ineffective stimulation. Location 2 (shown in the lower half of the figure) illustrates another scenario: although the area near the wellbore does not show obvious sweet spot characteristics, as the fractures expand in space, the main control area of ​​the fracturing and stimulation will eventually be located in the high sweet spot area. In this case, if the deployment plan is set according to the near-well sweet spot, the effective development area will be missed, resulting in a decrease in reservoir utilization efficiency.

[0079] Based on the aforementioned technical problems and needs, the inventive concept of this application aims to solve the problem that existing technologies rely solely on near-wellbore sweet spot information for fracturing deployment, making it difficult to accurately reflect the reservoir heterogeneity in the actual fracturing stimulation space. Specifically, this application uses the wellbore trajectory as a basis, combined with preset stimulation parameters in the fracturing project, to spatially divide the area to be analyzed, constructing multiple sub-regions to be analyzed. This ensures that the analysis area covers the spatial volume that fracturing may affect, rather than being limited to the local area on both sides of the wellbore. This spatial division method ensures the geometrical consistency between the analysis area of ​​the sweet spot distribution and the fracturing action area. Next, to achieve spatial alignment between the reservoir model and the actual stimulation area, based on the wellbore local coordinate system, a preset coordinate transformation algorithm is used to transform multiple model grid cells in the three-dimensional reservoir sweet spot distribution model constructed in the geodetic coordinate system to the current local coordinate system. This transformation process establishes a spatial mapping relationship between the fracturing direction and geological properties, enabling accurate determination of whether each model grid cell falls within a certain sub-region to be analyzed.

[0080] After establishing the spatial correspondence, the sweet spot indices of model grid cells falling within the sub-region to be analyzed are obtained and combined into a sweet spot index set for that sub-region. This sweet spot index set comprehensively reflects the reservoir quality that the sub-region may exhibit during actual fracturing stimulation. Finally, based on the sweet spot index sets of multiple sub-regions, this application outputs fracturing deployment information for the entire analyzed region, ensuring that fracturing segment division and deployment decisions are based on actual reservoir spatial attributes, thereby improving the accuracy of fracturing and the effectiveness of reservoir stimulation.

[0081] The technical solution of this application and how it solves the above-mentioned technical problems will be described in detail below with 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 this application will be described below with reference to the accompanying drawings.

[0082] Figure 2 is a flowchart illustrating the fracturing implementation deployment optimization method provided in an embodiment of this application. As shown in Figure 2, the method includes:

[0083] S21. Based on the wellbore trajectory of the area to be analyzed and the preset modification information corresponding to the wellbore trajectory, the area to be analyzed is spatially divided to obtain multiple sub-areas to be analyzed.

[0084] In this embodiment, the target reservoir area (i.e., the area to be analyzed) is spatially divided based on the wellbore trajectory and its corresponding preset stimulation information to construct multiple sub-regions to be analyzed. The wellbore trajectory refers to the actual path of the wellbore in three-dimensional space, typically consisting of a series of continuous spatial coordinate points formed by drilling measurement data. These coordinate points are arranged along the wellbore's depth measurement direction, reflecting the azimuth and dip changes of the wellbore at different depths. The preset stimulation information consists of spatial parameters set in the fracturing operation plan, typically including stimulation width, stimulation length, and stimulation height, corresponding to the set length of the fracturing section along the wellbore direction, the maximum lateral extension distance of the fracturing fracture, and the maximum vertical extension value of the fracture height, respectively. These parameters collectively define the boundaries of the three-dimensional area that the fracturing fracture may affect, providing a basis for constructing analysis units. The entire area to be analyzed can be divided into several sub-regions to be analyzed. Each sub-region can be considered as a representative unit of a fracturing action volume, used as the spatial carrier for subsequent steps such as sweet spot distribution identification, coordinate mapping, and attribute extraction. This division method effectively maps the wellbore trajectory to the fracturing stimulation space, improving the overall spatial accuracy and deployment guidance capability of the analysis.

[0085] S22, based on the trajectory segment corresponding to the current sub-region to be analyzed, obtain the current local coordinate system of the wellbore corresponding to the trajectory segment.

[0086] In this embodiment, for the current sub-region to be analyzed, it is necessary to obtain its corresponding trajectory segment and establish or call the corresponding wellbore local coordinate system based on the trajectory segment to provide a unified spatial reference framework for subsequent coordinate transformation and spatial attribution determination. The trajectory segment is a three-dimensional spatial segment formed by dividing the wellbore trajectory, reflecting the actual direction of that segment of the wellbore in the three-dimensional geological model. Since wellbore trajectories often exhibit non-linear shapes, different trajectory segments may belong to different wellbore local coordinate systems; however, in continuous areas where the trajectory direction does not change significantly, multiple trajectory segments can share the same wellbore local coordinate system. To ensure consistency in spatial mapping, coordinate transformation, and region determination for each segment, each trajectory segment is associated with a wellbore local coordinate system. The wellbore local coordinate system data can be stored as an auxiliary attribute of the wellbore trajectory, or a corresponding local coordinate system can be independently established for each segment during the division of the trajectory segments. The specific method can be flexibly set according to requirements, and the establishment of the local coordinate system can be done using existing technologies; no specific limitations are imposed here.

[0087] In practice, the first step is to locate the trajectory segment corresponding to the current sub-region to be analyzed and identify the wellbore local coordinate system information to which the trajectory segment belongs. If the trajectory segment already corresponds to an existing local coordinate system, its coordinate system parameters are directly called; if not yet established, a new local coordinate system is automatically constructed based on the spatial direction of the trajectory segment. Furthermore, the position of its origin in the geodetic coordinate system and its rotation relationship with the global coordinate system are recorded. Through this embodiment, a spatial projection foundation is established for each sub-region to be analyzed, realizing a unified expression of model coordinates and local modification space, thereby providing geometric references for subsequent operations such as coordinate transformation, spatial filtering, and attribute mapping. This method of constructing a local coordinate system based on trajectory segments improves the spatial analysis stability in complex trajectory scenarios such as curved wells and multi-branch wells.

[0088] S23, based on the constructed three-dimensional reservoir sweet spot distribution model, obtains the first coordinates of multiple model grid cells in the geodetic coordinate system in the area to be analyzed, and maps the first coordinates to the current wellbore local coordinate system through a preset coordinate transformation algorithm to obtain the second coordinates of multiple model grid cells.

[0089] In this embodiment, firstly, based on the constructed 3D reservoir sweet spot distribution model, multiple model grid cells in the area to be analyzed are identified, and the spatial location information of these model grid cells in the geodetic coordinate system, i.e., the first coordinates, is extracted. The 3D reservoir sweet spot distribution model is usually a reservoir attribute model obtained by inverting multi-source geological data such as seismic data, well logging data, and core analysis. Its structure consists of several regular model grid cells, each carrying spatial location (i.e., center point coordinates) and reservoir evaluation attributes such as the sweet spot index. To achieve geometric alignment between the geological model and the wellbore stimulation space, the spatial location of these model grid cells needs to be transformed from the geodetic coordinate system (usually using an absolute coordinate system of East-North-Height) to the wellbore local coordinate system corresponding to the current trajectory segment. The geodetic coordinate system reflects the global geographical location of the model within the entire reservoir area, while the wellbore local coordinate system is a local spatial system constructed with the current trajectory segment as a reference, and its direction is consistent with the wellbore strike. Therefore, the coordinate transformation process is essentially projecting the global location onto the local geometric system so as to subsequently determine which grid cells are located in the current sub-region to be analyzed. The coordinate mapping is completed through a preset coordinate transformation algorithm. After mapping, the obtained second coordinates represent the position of the model grid cell in the current wellbore local coordinate system. These second coordinates reflect the spatial distribution of the model grid cell relative to the trajectory segment, providing a basis for subsequent determination of whether it falls within the sub-region to be analyzed. This embodiment ensures that each data point can be accurately located within the fracturing range during the analysis process by establishing a geometric mapping between the reservoir geological model and the well section spatial structure.

[0090] S24. Based on the second coordinate of the model grid cell, when it is determined that the model grid cell is located in the current sub-region to be analyzed, the sweetness index of the model grid cell is obtained to obtain the sweetness index set corresponding to the current sub-region to be analyzed.

[0091] In this embodiment, based on the completed coordinate transformation, the second coordinates of multiple model grid cells in the current wellbore local coordinate system are obtained. These second coordinates reflect the relative position of each model grid cell in the spatial reference system corresponding to the current trajectory segment, facilitating the determination of whether it falls within the spatial range of the current sub-region to be analyzed. To achieve this determination, firstly, a set of spatial boundary judgment conditions, including length, width, and height dimensions, is constructed based on the geometric boundary conditions of the sub-region in the local coordinate system. For example, a sub-region can be considered as a rectangular prism or parallelepiped constructed with the trajectory segment as its central axis, its boundary defined by the modification width, modification length, and modification height. For each model grid cell, its second coordinates are compared one by one with the boundary conditions of the sub-region to be analyzed. If the coordinates of the model grid cell fall within the sub-region boundary range in all three directions, it can be determined that the model grid cell belongs to the current sub-region to be analyzed.

[0092] Furthermore, to reduce boundary misjudgments, a small boundary redundancy tolerance can be set to ensure that all grid cells with potential interaction are included in the judgment scope. Once a model grid cell is confirmed to belong to the current sub-region to be analyzed, the sweet spot index corresponding to that cell in the 3D reservoir sweet spot distribution model is extracted. The sweet spot indices of all model grid cells belonging to the current sub-region are extracted one by one and combined to form the sweet spot index set of the current sub-region to be analyzed. The sweet spot index set not only retains the information of reservoir attributes within the region, but also provides a data foundation for subsequent comprehensive analysis and optimal fracturing. By combining spatial attribution judgment with sweet spot index extraction, the mapping of 3D geological model attributes to fracturing analysis units is completed. This process ensures that fracturing deployment decisions are based on the spatial distribution of reservoir geological attributes, thereby improving the accuracy and controllability of the overall fracturing effect.

[0093] S25, based on the sweet spot index set corresponding to multiple sub-regions to be analyzed, output the fracturing implementation deployment information of the region to be analyzed.

[0094] In this embodiment, after extracting the sweet spot index sets for each sub-region to be analyzed, these data need to be summarized and analyzed to determine and output the fracturing deployment information for the entire sub-region to be analyzed. The fracturing deployment information refers to the optimal judgment and deployment strategy for fracturing segments based on reservoir quality indicators, including the spatial location of the fracturing segment, its potential for stimulation, and whether perforation clusters should be deployed. The goal is to identify fracturing target segments with high production potential through quantitative methods, thereby achieving precise deployment of fracturing energy and maximizing reservoir stimulation efficiency. Specifically, the sweet spot index set for each sub-region to be analyzed represents the set of sweet spot attribute values ​​for all model grid cells within that sub-region. These attribute values ​​are typically dimensionless scoring indicators used to reflect the comprehensive performance of development factors such as porosity, permeability, organic matter abundance, and brittleness of the local reservoir. First, the sweet spot index sets for each sub-region are statistically processed. This can be achieved through direct summation, mean calculation, or weighted aggregation to obtain a comprehensive sweet spot value, which is used to quantify the overall development potential of the sub-region to be analyzed.

[0095] By comprehensively assessing all sub-regions to be analyzed, complete fracturing deployment information can be generated, including the spatial distribution of priority fracturing sections, the recommended stimulation intensity for each section, and its relative priority with other well sections. This information provides clear construction references for field operations, while optimizing resource allocation, reducing ineffective stimulation, and improving single-well productivity and operational efficiency.

[0096] In one embodiment, Figure 3 is a schematic flowchart of a method for obtaining multiple sub-regions to be analyzed provided in this application embodiment. It is a specific description of one implementation of obtaining the sub-regions to be analyzed in step S21 above. Based on the above embodiment, as shown in Figure 3, it includes:

[0097] S31, Obtain the three-dimensional trajectory information of the wellbore trajectory, and determine the continuous coordinate point sequence of the wellbore trajectory along the depth measurement direction based on the three-dimensional trajectory information;

[0098] S32, obtain one or more local coordinate systems of the wellbore trajectory, and based on the local coordinate systems of the wellbore, divide the continuous coordinate point sequence according to the modification width in the preset modification information to obtain multiple trajectory segments;

[0099] S33, based on preset modification information, obtain the modification length and modification height, as well as the fracturing crack propagation direction corresponding to the modification length;

[0100] S34. Based on the modification length, fracturing fracture propagation direction, and modification height, multiple sub-regions to be analyzed are constructed by setting the trajectory sub-segment as the central axis.

[0101] In this embodiment, the area to be analyzed is divided into spatial units based on the wellbore trajectory and preset stimulation information. Specifically, firstly, the three-dimensional trajectory information of the wellbore is acquired. This three-dimensional trajectory information typically originates from drilling measurement data, such as Measurement While Drilling (MWD) or Logging While Drilling (LWD), and includes data on the positional changes of the wellbore throughout the drilling process. Using depth measurement as the main axis, a continuous sequence of coordinate points is formed, arranged along the wellbore extension direction. Next, one or more local coordinate systems corresponding to the wellbore trajectory are invoked. These local coordinate systems describe the spatial directional characteristics of the wellbore in different sections. Subsequently, the continuous sequence of coordinate points is divided based on the stimulation width parameter provided in the preset stimulation information. It is ensured that each segment falls within the corresponding local coordinate system, thereby obtaining multiple trajectory segments that are geometrically continuous and directionally consistent. It should be further explained that the modification width parameter is usually greater than or equal to twice the planar size of the model mesh cell in the three-dimensional reservoir sweet spot model. For example, when the planar size of the model mesh cell is 20m×20m, the modification width parameter should be at least 40m. The purpose is to ensure that there are model mesh cells that fall within the sub-region to be analyzed.

[0102] Based on the obtained trajectory segments, the modification length and modification height parameters from the preset modification information are further read, corresponding to the expected expansion scale of the fracturing fractures in the lateral and vertical directions, respectively. Simultaneously, combined with fracturing data or reservoir structural characteristics, the fracturing fracture expansion direction corresponding to the modification length direction is obtained, typically a direction parallel to the maximum principal stress or a direction forming a specific angle with the wellbore strike. Finally, with each trajectory segment as its central axis, a closed spatial unit is constructed in its three-dimensional spatial location. This spatial unit is consistent with the trajectory segment in the length direction, extends laterally according to the fracturing fracture length, and expands symmetrically in the vertical height according to the fracture height, thus forming a spatial volume unit, i.e., the sub-region to be analyzed. This sub-region to be analyzed will serve as the basic evaluation unit for subsequent sweet spot index projection and spatial screening, ensuring a high degree of spatial consistency between reservoir properties and fracturing deployment units. Through the above division method, not only is structural fusion between the geological model and the wellbore trajectory achieved, but also a basic unit for spatial attribute analysis within the reservoir modification range is established, providing structured geometric support for fracturing deployment decisions.

[0103] For example, Figure 4 is a schematic diagram of the planar structure of the region to be analyzed provided in an embodiment of this application. To more intuitively illustrate the relationship between the region to be analyzed and the wellbore trajectory, the region division is further explained here using Figure 4 as an example. The entire image uses a three-dimensional reservoir sweet spot distribution model as the background, and the model boundary is represented by a box, representing the overall range covered by the constructed three-dimensional geological model. Horizontal wellbores traverse the reservoir along a specific strike and are represented by blue lines. To facilitate analysis and processing related to fracturing deployment information, a computational domain (i.e., the region to be analyzed) containing the target wellbore needs to be selected within the three-dimensional model. As shown in the figure, the computational domain is represented by a dashed rectangle, with a length greater than or equal to the wellbore length and a width approximately equal to the fracturing fracture length, to ensure that the entire wellbore and fracturing influence range are included. The coordinate system of this computational domain is defined as the local wellbore coordinate system. As shown in Figure 4, the location of the fracturing fracture is represented by a light blue surface perpendicular to the wellbore, with the fracture center located in the middle of the wellbore. The boundary of the computational domain is set comprehensively based on the parameters of fracturing fracture length, wellbore length, and reservoir fracture height to ensure that the area affected by fracturing stimulation can be covered during the subsequent sweet spot unit screening and spatial positioning process.

[0104] Furthermore, in one specific embodiment, the implementation of obtaining multiple trajectory segments in step S32 above will be further explained here. Based on the above embodiment, it includes:

[0105] S321, filter and obtain multiple continuous coordinate points belonging to the same wellbore local coordinate system, and divide the multiple continuous coordinate points into equal intervals according to the modification width to obtain one or more trajectory sub-segments corresponding to the wellbore local coordinate system;

[0106] S322, traverse multiple wellbore local coordinate systems, obtain one or more trajectory segments corresponding to each wellbore local coordinate system, and obtain multiple trajectory segments.

[0107] In this embodiment, the wellbore local coordinate system is a spatial reference system established for sections of the wellbore trajectory with relatively consistent directions. It typically includes a coordinate origin and a direction vector, and can describe the local characteristics of the wellbore's orientation within that section. In actual engineering, a wellbore trajectory usually covers multiple sections with varying directions, thus resulting in multiple wellbore local coordinate systems. Each wellbore local coordinate system corresponds to a trajectory segment (including one or more trajectory sub-segments) with relatively consistent geometric directions. First, all coordinate points in the wellbore trajectory are filtered and categorized according to their respective wellbore local coordinate systems. For example, trajectory points belonging to local coordinate system A are grouped into one set, those belonging to local coordinate system B into another set, and so on. For multiple consecutive coordinate points belonging to the same wellbore local coordinate system, their arrangement order in the wellbore sounding direction is extracted. Without crossing coordinate systems, the sequence of coordinate points is divided at equal intervals based on the modification width parameter in the preset modification information. When the cumulative distance reaches the modification width, a complete trajectory sub-segment is formed, and the start and end coordinates of this segment are recorded. Subsequently, all wellbore local coordinate systems are traversed. For each wellbore local coordinate system, the above filtering and partitioning steps are repeated to extract a set of trajectory segments corresponding to that coordinate system. These trajectory segments will serve as the central axis for the spatial construction of the fracturing unit, and will be further used to construct the sub-region to be analyzed, thereby achieving spatial fusion and attribute association between the wellbore path and the reservoir geological model.

[0108] For example, Figure 5 is a three-dimensional structural diagram of the division of sub-regions to be analyzed provided in an embodiment of this application. The size of the computational domain (region to be analyzed) covers the horizontal wellbore and its fracturing influence range. The wellbore trajectory is a three-dimensional pipeline model with a curved shape, located at the center of the computational domain. Along different directions of the wellbore trajectory, combined with a preset modification width, the wellbore trajectory is spatially divided to obtain multiple trajectory segments. Several sub-regions to be analyzed (i.e., vertical evaluation units shown in the figure) are constructed around each trajectory segment as a central axis. The spatial range of each sub-region to be analyzed is represented by a transparent rectangular envelope, and the spatial size is determined by the length of the trajectory segment, the length of the fracturing fracture, and the fracture height. In the enlarged view in the upper right corner of Figure 5, another type of evaluation unit (sub-region to be analyzed) is shown: an inclined evaluation unit. A vertical evaluation unit means that the plane of the evaluation unit is perpendicular to the wellbore trajectory, that is, the fracturing fracture extends in a direction orthogonal to the wellbore; while an inclined evaluation unit means that there is an angle between the fracturing fracture and the wellbore trajectory. In this scenario, the configuration of the evaluation unit needs to be adjusted according to the included angle to ensure it accurately encompasses the main control area of ​​the fracturing fracture. Specifically, the major axis of the evaluation unit is parallel to the trajectory segment, and the minor axis is parallel to the fracturing propagation direction. Figure 5 visually illustrates the process of constructing sub-regions of analysis at different angles and spatial scales starting from the trajectory segment, and also demonstrates the spatial geometric relationship between the sub-region of analysis and the fracturing fracture and wellbore trajectory in three-dimensional space. This division method effectively captures the sweet spot distribution characteristics within the fracturing stimulation range, laying a spatial foundation for subsequent coordinate mapping, sweet spot index screening, and calculation of fracturing implementation deployment information.

[0109] In one embodiment, the first coordinates of the model mesh element are obtained in step S23 above. A specific implementation method is provided here. Based on the above embodiment, it includes:

[0110] S231, Obtain the constructed three-dimensional reservoir sweet spot distribution model; wherein, the three-dimensional reservoir sweet spot distribution model is composed of multiple model grid cells, and each model grid cell has a unique spatial index and attribute parameters;

[0111] S232, select multiple model grid cells located within the area to be analyzed, and extract the center point coordinates of the model grid cells in the geodetic coordinate system, and use the center point coordinates as the first coordinates of the model grid cells.

[0112] In this embodiment, a pre-constructed three-dimensional reservoir sweet spot distribution model is first invoked as the basic data structure for analyzing the spatial distribution of reservoir quality. This three-dimensional reservoir sweet spot distribution model is typically constructed using geological modeling software (such as Petrel) based on multi-source geological data, including seismic exploration datasets, well logging parameters, and core analysis results. Each model grid cell is the basic building block of the model. Each model grid cell has a unique spatial index to identify its position within the entire three-dimensional model structure and simultaneously contains multiple reservoir attribute parameters, typically including porosity, permeability, brittleness index, and organic matter abundance. These parameters are fused and calculated to form a comprehensive sweet spot index. A higher sweet spot index value indicates that the reservoir at that location has higher fracturing potential and production response capability. It should be noted that the three-dimensional reservoir sweet spot model can be constructed using existing technologies; the purpose of this application is to obtain the corresponding sweet spot index, therefore, no specific restrictions are placed on the construction of the three-dimensional reservoir sweet spot model.

[0113] To achieve coupled calculations with wellbore stimulation space, the specific locations of model grid cells in geographic space need to be extracted. In this embodiment, the 3D sweet spot distribution model is screened, and all model grid cells located within the boundary of the current analysis area are extracted. The boundary of the analysis area is usually centered on the wellbore trajectory, forming a spatial envelope with fracturing settings parameters. Only model grid cells located within or on the boundary of this envelope are selected as analysis objects. For each selected model grid cell, its geometric center point coordinates in the geodetic coordinate system are further extracted. This center point is usually determined by the geometry of the cell grid and serves as the representative position of the cell in subsequent coordinate transformations and spatial judgments. The extracted center point coordinates are recorded as the first coordinates of the model grid cell, serving as the input parameter for mapping from the geological model to the local wellbore stimulation space. In summary, this embodiment, through processing the 3D reservoir sweet spot distribution model, transforms the reservoir geological attributes from a global representation to a local area related to wellbore stimulation, ensuring analysis efficiency and providing a high-precision, structured input basis for geological control in fracturing deployment.

[0114] In one embodiment, Figure 6 is a schematic flowchart of a method for obtaining the second coordinates of a model mesh element provided in this application embodiment. An implementation of obtaining the second coordinates of the model mesh element in step S23 above is provided here. Based on the above embodiment, as shown in Figure 6, it includes:

[0115] S61, record the coordinates of the origin of the current wellbore local coordinate system in the geodetic coordinate system as the reference point coordinates; wherein, the geodetic coordinate system and the current wellbore local coordinate system are a common Z-axis coordinate system;

[0116] S62, based on the geodetic coordinate system and the current wellbore local coordinate system, obtain the horizontal azimuth rotation angle of the geodetic coordinate system and the current wellbore local coordinate system;

[0117] S63: Based on the first coordinates of the model grid cells, the coordinates of the reference point, and the horizontal azimuth rotation angle, the first coordinates are mapped to the current local coordinate system of the wellbore to obtain the second coordinates of multiple model grid cells.

[0118] In this embodiment, firstly, the origin of the current wellbore local coordinate system is determined, and its spatial coordinates in the geodetic coordinate system are obtained. These coordinates represent the absolute position of the starting point of the wellbore trajectory segment in the global three-dimensional coordinate system (e.g., a coordinate system with east, north, and elevation axes), and are recorded as reference point coordinates. The reference point coordinates are used to perform the translation operation of the coordinate origin during subsequent transformations and serve as the reference parameter connecting the global and local systems in the coordinate transformation. Secondly, the wellbore trajectory may have rotational differences from the geodetic coordinate axes on the horizontal plane, so the horizontal azimuth rotation angle between the geodetic coordinate system and the current wellbore local coordinate system needs to be calculated. This angle is usually determined by the azimuth angle of the wellbore trajectory segment, representing the angle required to rotate counterclockwise from the X-axis of the geodetic coordinate system (e.g., east) to the X-axis of the wellbore local coordinate system (along the trajectory direction). Since the Z-axis of both the geodetic coordinate system and the wellbore local coordinate system are perpendicular to the ground, meaning the two coordinate systems are consistent in the vertical direction, the transformation can be completed simply by performing a two-dimensional coordinate rotation in the horizontal plane.

[0119] After parameter preparation, coordinate transformation is performed on the first coordinate of each model grid cell (i.e., the coordinates of its center point in the geodetic coordinate system). For example, the transformation process includes two steps: the first step is translation, aligning it with the coordinate origin; the second step is rotation, performing a two-dimensional rotation matrix transformation on the translated coordinates based on the horizontal azimuth rotation angle, mapping them to the current wellbore local coordinate system. The transformation result is the second coordinate of the model grid cell in local space, reflecting its positional relationship relative to the wellbore trajectory direction. After coordinate transformation, the schematic diagram shown in Figure 7 is obtained. Figure 7 is a schematic diagram of the coordinate transformation structure provided in this embodiment. Through this coordinate transformation process, localized mapping of the three-dimensional geological attributes of the reservoir is achieved, enabling subsequent operations such as determining whether the grid falls within the sub-region to be analyzed and extracting the sweet spot index to be performed within the wellbore-dominated spatial framework, improving the accuracy of the judgment and the consistency of engineering control.

[0120] In one specific embodiment, in step S43 above, the first coordinates are mapped to the current wellbore local coordinate system based on the first coordinates of the model grid cells, the coordinates of the reference point, and the horizontal azimuth rotation angle to obtain the second coordinates of multiple model grid cells. A specific implementation method is provided here. Based on the above embodiment, it includes:

[0121] S431, based on the first coordinate (x) of the model mesh element p y p , z p The coordinates of the reference point and the horizontal azimuth rotation angle are determined using the following formula:

[0122]

[0123] S432, calculate and obtain the second coordinate (x') of the model mesh element. p y' p , z' p );in, and θ represents the x-coordinate and y-coordinate of the reference point, respectively; θ is the horizontal azimuth rotation angle.

[0124] In this embodiment, to achieve the spatial projection transformation from the geodetic coordinate system to the wellbore local coordinate system, coordinate transformation calculations are performed on the first coordinate of each model grid cell. Specifically, the first coordinate of each model grid cell is (x... p y p , z p ), representing the horizontal, vertical, and lateral coordinates of the model's grid cell in the geodetic coordinate system, respectively. Simultaneously, the reference point coordinates... and This represents the two-dimensional planar position of the origin of the current wellbore local coordinate system in the geodetic coordinate system. The horizontal azimuth rotation angle θ is the angle between the direction of the current trajectory segment and the X-axis of the geodetic coordinate system, measured counterclockwise, in radians or degrees. The coordinate transformation consists of two steps: The first step is to translate the first coordinate of the model mesh element from the origin of the geodetic coordinate system to the origin of the wellbore local coordinate system, making it referenced to the local coordinate system. The second step is to perform a two-dimensional rotation on the translated coordinates. The rotation uses a standard two-dimensional coordinate rotation matrix:

[0125]

[0126] This matrix transforms the coordinates on the horizontal plane while keeping the vertical coordinates unchanged, thereby obtaining the second coordinate (x') in the local coordinate system of the wellbore. p y' p , z' p After completing the above calculations, the spatial position of each model grid cell in the current wellbore local coordinate system can be obtained. This positional data is used to subsequently determine whether it falls within the sub-region to be analyzed. This conversion process achieves geometric unification between the geological model and the well section stimulation space, ensuring that fracturing deployment decisions can be made based on the distribution of reservoir structure.

[0127] Furthermore, the derivation process of the above coordinate transformation formula is provided here to more clearly explain the origin of the coordinate transformation formula. Figure 8 is a schematic diagram of two-dimensional coordinate transformation under different coordinate systems provided in the embodiments of this application. As shown in Figure 8, let point P be the center point of any model grid cell in the reservoir, and its coordinates in the geodetic coordinate system be (x... p y p , z p Let the geodetic coordinate system xoy be the global spatial reference, which constructs a two-dimensional plane using unit vectors e1 and e2 as basis vectors. The wellbore local coordinate system x'o'y' is a wellbore local coordinate system that varies with the direction of the trajectory segments, and its corresponding basis vectors are e1' and e2'. According to the vector conservation law of coordinate transformation, the coordinates of point P in both coordinate systems should satisfy the following relationship:

[0128]

[0129] in, , , , θ is the angle by which the geodetic plane coordinate system xoy is rotated counterclockwise to the wellbore plane coordinate system x'o'y' (i.e., the horizontal azimuth rotation angle).

[0130] Substituting the above unit vector and solving for the two-dimensional coordinate transformation formula of the model grid cell center point in the wellbore local coordinate system, we obtain the following formula:

[0131]

[0132] Considering the absolute position of the origin of the wellbore local coordinate system in the geodetic coordinate system, the final three-dimensional coordinates of point P in the model mesh element in the wellbore local coordinate system are:

[0133]

[0134] Where Δx and Δy are the lateral and longitudinal offsets of the origin of the wellbore local coordinate system in the geodetic coordinate system, respectively, while the z-coordinate remains unchanged (i.e., a common z-axis coordinate system). The above formula, by introducing a combination of a two-dimensional rotation matrix and a translation vector of the coordinate origin, not only ensures the geometric consistency between coordinate systems but also simplifies the implementation logic of spatial transformation.

[0135] Furthermore, in one specific embodiment, step S24 above determines that the model mesh element is located in the current sub-region to be analyzed, providing a method for determining this situation. Based on the above embodiment, it includes:

[0136] S2411, when the angle between the direction of the hydraulic fracture propagation and the trajectory segment is 90°, if the second coordinate (x') of the model mesh element... p y' p , z' p Satisfies the formula:

[0137]

[0138] This determines that the model mesh element is located in the current sub-region to be analyzed; where z w Let L be the vertical coordinate of the left endpoint of the trajectory segment, and let L be the endpoint closest to the origin of the local coordinate system of the wellbore; w To modify the width (the length of the corresponding trajectory segment), L f H represents the length of the fracturing operation (perpendicular to the wellbore direction, corresponding to the length of the fracturing fracture), and H represents the height of the fracturing operation (i.e., the height of the corresponding fracturing fracture).

[0139] In this embodiment, the propagation direction of the fracturing fracture is orthogonal to the wellbore trajectory, i.e., a vertical fracture propagation with an included angle β of 90°. In the wellbore local coordinate system, the dimensional parameters of this spatial unit are defined, including its length along the wellbore strike direction, its width perpendicular to the fracturing direction, and its height along the vertical direction. Simultaneously, to facilitate the limitation of the three-dimensional spatial range, the coordinates of the starting point of the trajectory segment in the Z-axis direction are used as the reference for calculating the upper and lower boundaries of the spatial range. The spatial coordinates of the model mesh unit in the local coordinate system are denoted as (x'...). p y' p , z' p The system performs a three-dimensional boundary determination on the spatial location of the reservoir. If the above conditions are met, the reservoir is considered to fall within the current sub-region to be analyzed. The determination method provided in this embodiment achieves a precise mapping between fracturing parameters and reservoir distribution, providing reliable data support for the selection of fracturing sections and the deployment of perforation clusters, and has engineering practicality for achieving efficient spatial matching.

[0140] For example, assuming the current trajectory segment length is 60m, the fracturing fracture length is 100m, the fracture height is 20m, and the vertical coordinate of the trajectory segment endpoint is 2500m, then the resulting sub-region range is: Lateral range (along the trajectory segment direction): 0 <x' p <60m; Lateral range (fracture width direction perpendicular to the trajectory direction): -50m <y' p <50m; Vertical range (seam height range): 2490m <z' p <2510m. If the second coordinate of a certain model mesh element is (15, 20, 2503), then all the above judgment conditions are met, and therefore the model mesh element is located in the current sub-region to be analyzed.

[0141] In another specific embodiment, step S24 above determines that the model mesh element is located in the current sub-region to be analyzed. Here, another method for determining this situation is provided. To address the situation where the direction of the fracturing fracture propagation is not perpendicular to the wellbore trajectory (i.e., the angle β is less than 90°), the original spatial screening conditions need to be adjusted to accommodate the change in shape of the sub-region to be analyzed due to the inclined fracture. In this case, the cross-section of the sub-region to be analyzed is no longer a simple cuboid, but a spatially inclined structure after tilting along the direction of the fracturing fracture propagation. Therefore, the three-dimensional position determination of the model mesh element in the local wellbore coordinate system requires the introduction of the angle parameter β. Based on the above embodiment, the following is included:

[0142] S2421, when the angle between the fracturing fracture propagation direction and the wellbore is less than 90°, if the second coordinate (x') of the model mesh element... p y' p , z' p Satisfies the formula:

[0143]

[0144] This determines that the model mesh element is located in the current sub-region to be analyzed; where, L w To modify the width (the length of the corresponding trajectory segment), L f H is the length of the fracturing fracture (perpendicular to the wellbore direction, corresponding to the length of the fracturing fracture), and H is the height of the fracturing fracture (i.e., the height of the corresponding fracturing fracture); z w β is the vertical coordinate of the left endpoint of the trajectory segment, and the left endpoint of the trajectory segment is the endpoint closest to the origin of the local coordinate system of the wellbore. β is the angle between the direction of the fracturing fracture propagation and the wellbore.

[0145] In this embodiment, the inequality reflects that the lateral expansion range of the crack is a variable that varies with x'. p The varying trapezoidal spatial region, its shape controlled by the included angle β, more closely approximates the expansion space formed by actual crack offset. Furthermore, within the defined height range, z... w The reference height position is provided, and H represents the total thickness of the upper and lower modifications.

[0146] S2422, when the angle between the fracturing fracture propagation direction and the wellbore is less than 90°, if the second coordinate (x') of the model mesh element... p y' p , z' p Satisfies the formula:

[0147]

[0148] This determines that the model mesh element is located in the current sub-region to be analyzed; where, L wTo modify the width (the length of the corresponding trajectory segment), L f H is the length of the fracturing fracture (perpendicular to the wellbore direction, corresponding to the length of the fracturing fracture), and H is the height of the fracturing fracture (i.e., the height of the corresponding fracturing fracture); z w β is the vertical coordinate of the left endpoint of the trajectory segment, and the left endpoint of the trajectory segment is the endpoint closest to the origin of the local coordinate system of the wellbore. β is the angle between the direction of the fracturing fracture propagation and the wellbore.

[0149] S2423, when the angle between the fracturing fracture propagation direction and the wellbore is less than 90°, if the second coordinate (x') of the model mesh element... p y' p , z' p Satisfies the formula:

[0150]

[0151] This determines that the model mesh element is located in the current sub-region to be analyzed; where, L w To modify the width (the length of the corresponding trajectory segment), L f H is the length of the fracturing fracture (perpendicular to the wellbore direction, corresponding to the length of the fracturing fracture), and H is the height of the fracturing fracture (i.e., the height of the corresponding fracturing fracture); z w β is the vertical coordinate of the left endpoint of the trajectory segment, and the left endpoint of the trajectory segment is the endpoint closest to the origin of the local coordinate system of the wellbore. β is the angle between the direction of the fracturing fracture propagation and the wellbore.

[0152] In practice, the angle β between the current trajectory segment and the fracture direction is determined, and the applicable spatial determination formula is switched based on this angle. This improves the adaptability of spatial analysis of the fracturing segment. Through this angle-adaptive coordinate filtering mechanism, it is possible to more accurately identify which model mesh elements may participate in the fracturing fracture modification, thereby improving the effectiveness of sweet spot index acquisition and ensuring that subsequent fracturing deployment information has a clear spatial physical basis.

[0153] In one embodiment, step S25 above outputs fracturing deployment information for the analyzed region based on the sweet spot index set corresponding to multiple sub-regions to be analyzed. A specific implementation method is provided here. Based on the above embodiment, it includes:

[0154] S251, Based on one or more dessert indices in the dessert index set, calculate the comprehensive dessert value for each sub-region to be analyzed by summing them;

[0155] S252, if the overall sweet spot value is greater than or equal to the sweet spot threshold, then the sub-region to be analyzed is recorded as the priority fracturing segment, and fracturing implementation deployment information carrying the priority fracturing segment and the uniformly deployed perforation cluster of the priority fracturing segment is output.

[0156] In this embodiment, the overall sweetness level of the sub-region under analysis is calculated by processing the sweetness index of all model grid cells in the current sub-region under analysis. First, the sweetness indices of multiple model grid cells previously selected within the current sub-region under analysis are summed to obtain the comprehensive sweetness value of the current sub-region under analysis. This comprehensive sweetness value is used to reflect the potential production capacity level of the current sub-region under analysis in fracturing stimulation.

[0157] For example, using the formula:

[0158]

[0159] Among them, D ijk Let be the sweet spot index corresponding to the model mesh cell with coordinates (i, j, k); m, n, and l are the number of mesh cells along the i, j, and k directions in the local coordinate system oijk, respectively. The triple summation symbol indicates that each model mesh cell needs to be traversed sequentially in the three spatial dimensions (i, j, k) during the calculation. The calculation result can serve as an indicator for subsequent fracturing segment selection and also provides a quantitative basis for forming information on fracturing implementation and deployment.

[0160] Subsequently, the obtained comprehensive sweet spot value is compared with a preset sweet spot threshold. This threshold is set by the staff during the fracturing preparation stage, based on historical production performance, reservoir evaluation standards, and economic and technical indicators, and is used to distinguish between areas that are "prioritized for fracturing" and areas that are "delayed or excluded." When the comprehensive sweet spot value of a sub-region to be analyzed is greater than or equal to the sweet spot threshold, it indicates that the region has good geological and mechanical conditions and possesses high fracturing stimulation efficiency and production response potential. Therefore, this sub-region is marked as a priority fracturing section. For sub-regions identified as priority fracturing sections, fracturing implementation deployment information will be further output. In this embodiment, the fracturing implementation deployment information includes the spatial layout of perforation clusters. To ensure that fracturing fractures expand uniformly in high-quality sweet spot areas and improve the uniformity of stimulation, multiple perforation clusters can be uniformly arranged within the priority fracturing section. The purpose of uniform arrangement is to allow the fracture network to contact the sweet spot area more extensively, thereby maximizing the release of reservoir potential. The spacing between perforation clusters can be automatically adjusted according to parameters such as fracture length, fracture height, and construction pressure to meet the requirements of wellbore stability and construction safety, and is not specifically limited here. This embodiment completes the logic from sweet spot index to fracturing deployment, and constructs a data-driven fracturing optimization strategy oriented towards reservoir heterogeneity. This improves the scientific rigor and accuracy of fracturing deployment.

[0161] It's important to note that the sweet spot index primarily analyzes the natural advantages of a reservoir, such as porosity, permeability, rock brittleness, and stress environment. These characteristics indicate the inherent potential of the oil and gas reservoir. The fracture-controlled fracturing index, on the other hand, focuses on the ability of hydraulic fracturing operations to transform similar or identical rock mechanical parameters and stress conditions into an effective, interconnected fracture network through fracture control techniques. In fact, if a reservoir has a significant advantage in the sweet spot index, its natural physical properties provide a good foundation for fracture formation and propagation. This also means that under good construction control, it is easier to achieve a highly efficient fracture network (i.e., a higher fracture-controlled fracturing index). Therefore, measuring the fracture-controlled fracturing index not only verifies the effectiveness of fracturing operations but also confirms that the reservoir advantages analyzed through the sweet spot index have been successfully translated into an effective path for increased production.

[0162] Figure 9 is a schematic diagram of the comparative analysis results of the implementation cases provided in this application. In a practical application well, to verify the effectiveness of the fracture-controlled fracturing index in fracturing stimulation, that is, the effectiveness of analyzing the distribution of the sweet spot index in the reservoir, a comparative analysis was carried out. Figure 9 shows the difference between the fracture-controlled fracturing index profile and the conventional logging interpretation fracturing index profile corresponding to a certain horizontal well. In Figure 9, the fracture-controlled fracturing index and the logging interpretation fracturing index are plotted on the left and right vertical axes, respectively, with the well depth as the horizontal axis, reflecting the spatial variation of fracturing capability in different sections of the wellbore along the depth sounding direction.

[0163] Within well section 1 (2180m~2480m), both index curves showed a downward trend, indicating that the reservoir sweet spots near the wellbore and within the fracturing area were generally poor, resulting in limited engineering fracturing capability. The consistent trends of the two types of curves suggest that the near-well and far-well regions in this section have relatively consistent fracturing capability. However, in well section 2 (3135m~3330m), a difference emerged between the fracture-controlled fracturing capability index and the well-logged interpreted fracturing capability index. The fracture-controlled index profile remained at a relatively high level (above 0.75), while the well-logged interpreted index showed a significant downward trend, with an overall value of approximately 0.6, indicating a trend lower than the fracture-controlled index. The key reason for this difference is that the fracturing area corresponding to well section 2 still contains a large number of engineering sweet spot grid cells in the far-well region. This area is not covered in the well-logging curves and therefore is not reflected in the conventional fracturing capability interpretation profile. In contrast, the fracture-controlled fracturing capability index comprehensively considers the sweet spot distribution within the entire sub-region that the fracturing fractures may extend into, thus more accurately reflecting the actual stimulation potential of the reservoir segment. As the above comparison shows, well logging interpretation profiles primarily reflect the reservoir quality in the vicinity of the wellbore, lacking the ability to analyze the overall scope of fracturing stimulation and potentially missing sweet spots in distant wells, thereby affecting the accuracy of fracturing deployment. The fracture-controlled fracturing capability index, on the other hand, comprehensively considers the spatial attributes of the stimulated volume and the distribution of sweet spots, enhancing the engineering guidance value of single-well profiles. This case fully validates the practicality and accuracy of the fracturing implementation and deployment optimization method proposed in this application under complex heterogeneous reservoir conditions.

[0164] Figure 10 is a schematic diagram of the structure of the optimization device provided in this application. As shown in Figure 10, the optimization device 10 provided in this embodiment includes:

[0165] The region division module 101 is used to spatially divide the region to be analyzed based on the well trajectory of the region to be analyzed and the preset modification information corresponding to the well trajectory, and obtain multiple sub-regions to be analyzed.

[0166] The coordinate system acquisition module 102 is used to acquire the current wellbore local coordinate system corresponding to the trajectory sub-segment based on the current sub-region to be analyzed.

[0167] The coordinate mapping module 103 is used to obtain the first coordinates of multiple model grid cells in the geodetic coordinate system in the area to be analyzed based on the constructed three-dimensional reservoir sweet spot distribution model, and to map the first coordinates to the current wellbore local coordinate system through a preset coordinate transformation algorithm to obtain the second coordinates of multiple model grid cells.

[0168] The dessert index acquisition module 104 is used to acquire the dessert index of the model grid cell based on the second coordinate of the model grid cell when it is determined that the model grid cell is located in the current sub-region to be analyzed, so as to obtain the dessert index set corresponding to the current sub-region to be analyzed;

[0169] The deployment information output module 105 is used to output fracturing implementation deployment information for the region to be analyzed based on the sweet spot index set corresponding to multiple sub-regions to be analyzed.

[0170] The optimization device 10 provided in this embodiment can execute the method provided in the above method embodiment. Its implementation principle and technical effect are similar, and will not be described in detail here.

[0171] Figure 11 is a schematic diagram of the structure of the electronic device provided in this application. As shown in Figure 11, the electronic device 11 provided in this embodiment includes at least one processor 111 and a memory 112. Optionally, the electronic device 11 further includes a communication component 113. The processor 111, the memory 112, and the communication component 113 are connected via a bus 114.

[0172] In a specific implementation, at least one processor 111 executes computer execution instructions stored in memory 112, causing at least one processor 111 to perform the above-described method.

[0173] The specific implementation process of processor 111 can be found in the above method embodiments, and its implementation principle and technical effect are similar. It will not be repeated here.

[0174] In the above embodiments, it should be understood that the processor 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.

[0175] The memory may include random access memory (RAM) and may also include non-volatile memory (NVM), such as at least one disk storage device.

[0176] The bus can be an Industry Standard Architecture (ISA) bus, a Peripheral Component Interconnect (PCI) bus, or an Extended Industry Standard Architecture (EISA) bus, etc. Buses can be categorized as address buses, data buses, control buses, etc. For ease of illustration, the buses shown in the accompanying drawings are not limited to a single bus or a single type of bus.

[0177] This application also provides a computer program product, including a computer program that, when executed by a processor, implements the above-described method.

[0178] This application also provides a computer-readable storage medium storing computer-executable instructions, which, when executed by a processor, implement the above-described method.

[0179] 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.

[0180] 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 an Application Specific Integrated Circuit (ASIC). Alternatively, the processor and the readable storage medium can exist as discrete components in the device.

[0181] The division of units is merely a logical functional division; in actual implementation, there may be other division methods. For example, multiple units or components may be combined or integrated into another system, or some features may be ignored or not executed. Furthermore, the coupling or direct coupling or communication connection shown or discussed may be indirect coupling or communication connection through some interfaces, devices, or units, and may be electrical, mechanical, or other forms.

[0182] In addition, the functional units in the various embodiments of the present invention can be integrated into one processing unit, or each unit can exist physically separately, or two or more units can be integrated into one unit.

[0183] If a function is implemented as a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of this invention, or the part that contributes to the prior art, or a part of the technical solution, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute all or part of the steps of the methods of the various embodiments of this invention. The aforementioned storage medium includes various media capable of storing program code, such as USB flash drives, portable hard drives, read-only memory (ROM), random access memory (RAM), magnetic disks, or optical disks.

[0184] Those skilled in the art will understand that all or part of the steps of the above-described method embodiments can be implemented by hardware related to program instructions. The aforementioned program can be stored in a computer-readable storage medium. When executed, the program performs the steps of the above-described method embodiments; and the aforementioned storage medium includes various media capable of storing program code, such as ROM, RAM, magnetic disks, or optical disks.

[0185] Finally, it should be noted that other embodiments of the invention will readily occur to those skilled in the art upon consideration of the specification and practice of the invention disclosed herein. This invention is intended to cover any variations, uses, or adaptations of the invention that follow the general principles of the invention and include common knowledge or customary techniques in the art not disclosed herein, and is not limited to the precise structures described above and shown in the accompanying drawings, and various modifications and changes can be made without departing from its scope. The scope of the invention is limited only by the appended claims.

Claims

1. A method for optimizing the deployment of fracturing operations, characterized in that, include: Based on the wellbore trajectory of the area to be analyzed and the preset modification information corresponding to the wellbore trajectory, the area to be analyzed is spatially divided to obtain multiple sub-areas to be analyzed. Based on the trajectory segment corresponding to the current sub-region to be analyzed, obtain the current wellbore local coordinate system corresponding to the trajectory segment; based on the constructed three-dimensional reservoir sweet spot distribution model, obtain the first coordinates of multiple model grid units in the geodetic coordinate system in the sub-region to be analyzed, and map the first coordinates to the current wellbore local coordinate system through a preset coordinate transformation algorithm to obtain the second coordinates of multiple model grid units; based on the second coordinates of the model grid units, when it is determined that the model grid unit is located in the current sub-region to be analyzed, obtain the sweet spot index of the model grid unit to obtain the sweet spot index set corresponding to the current sub-region to be analyzed; based on the sweet spot index set corresponding to multiple sub-regions to be analyzed, output the fracturing implementation deployment information of the sub-region to be analyzed; The method of obtaining the first coordinates of multiple model grid cells in the geodetic coordinate system based on the constructed 3D reservoir sweet spot distribution model includes: obtaining the constructed 3D reservoir sweet spot distribution model; wherein the 3D reservoir sweet spot distribution model is composed of multiple model grid cells, and each model grid cell has a unique spatial index and attribute parameters; filtering out multiple model grid cells located within the scope of the area to be analyzed, and extracting the center point coordinates of the model grid cells in the geodetic coordinate system, and using the center point coordinates as the first coordinates of the model grid cells; and mapping the first coordinates to the first coordinates in the geodetic coordinate system using a preset coordinate transformation algorithm. To obtain the second coordinates of multiple model grid cells in the current wellbore local coordinate system, the following steps are taken: recording the coordinates of the origin of the current wellbore local coordinate system in the geodetic coordinate system as reference point coordinates; wherein the geodetic coordinate system and the current wellbore local coordinate system are a common Z-axis coordinate system; obtaining the horizontal azimuth rotation angle of the geodetic coordinate system and the current wellbore local coordinate system based on the geodetic coordinate system and the current wellbore local coordinate system; and mapping the first coordinates of the model grid cells to the current wellbore local coordinate system based on the first coordinates of the model grid cells, the reference point coordinates, and the horizontal azimuth rotation angle to obtain the second coordinates of multiple model grid cells.

2. The method according to claim 1, characterized in that, The step involves spatially dividing the area to be analyzed based on the well trajectory and the corresponding preset modification information to obtain multiple sub-regions. This includes: acquiring three-dimensional trajectory information of the well trajectory and determining a continuous sequence of coordinate points along the depth sounding direction based on the three-dimensional trajectory information; acquiring one or more local coordinate systems corresponding to the well trajectory and dividing the continuous sequence of coordinate points based on the local coordinate systems and the modification width in the preset modification information to obtain multiple trajectory segments; acquiring the modification length and modification height based on the preset modification information, and acquiring the fracturing fracture propagation direction corresponding to the modification length; and constructing a sub-region corresponding to the trajectory segment by setting the trajectory segment as the central axis based on the modification length, fracturing fracture propagation direction, and modification height to obtain multiple sub-regions.

3. The method according to claim 2, characterized in that, The step of dividing the continuous coordinate point sequence into equal intervals based on the wellbore local coordinate system and the modification width in the preset modification information to obtain multiple trajectory segments includes: filtering and obtaining multiple continuous coordinate points belonging to the same wellbore local coordinate system, and dividing the multiple continuous coordinate points into equal intervals based on the modification width to obtain one or more trajectory segments corresponding to the wellbore local coordinate system; traversing multiple wellbore local coordinate systems to obtain one or more trajectory segments corresponding to each wellbore local coordinate system to obtain multiple trajectory segments.

4. The method according to claim 1, characterized in that, The step of mapping the first coordinates to the current wellbore local coordinate system based on the first coordinates of the model grid cells, the reference point coordinates, and the horizontal azimuth rotation angle, and obtaining the second coordinates of multiple model grid cells, includes: based on the first coordinates (x, y) of the model grid cells... p y p , z p The coordinates of the reference point and the horizontal azimuth rotation angle are determined using the following formula: Calculate and obtain the second coordinate (x') of the model mesh element. p y' p , z' p );in, and θ represents the x-coordinate and y-coordinate of the reference point, respectively; θ is the horizontal azimuth rotation angle.

5. The method according to claim 2, characterized in that, Determining the location of the model mesh element in the current sub-region to be analyzed based on its second coordinate includes: when the angle between the fracturing fracture propagation direction and the trajectory segment is 90°, if the second coordinate (x') of the model mesh element... p y' p , z' p Satisfies the formula: Then it is determined that the model mesh element is located in the current sub-region to be analyzed; where, L w To modify the width, L f H represents the length of the modification, and H represents the height of the modification; z w The left endpoint of the trajectory segment is the vertical coordinate of the left endpoint of the trajectory segment, and the left endpoint of the trajectory segment is the endpoint closest to the origin of the local coordinate system of the wellbore.

6. The method according to claim 2, characterized in that, When the angle between the fracturing fracture propagation direction and the wellbore is less than 90°, if the second coordinate (x') of the model mesh element... p y' p , z' p Satisfies the formula: or, or, Then it is determined that the model mesh element is located in the current sub-region to be analyzed; where, L w To modify the width, L f H represents the length of the modification, and H represents the height of the modification; z w β is the vertical coordinate of the left endpoint of the trajectory segment, and the left endpoint of the trajectory segment is the endpoint closest to the origin of the local coordinate system of the wellbore, and β is the angle between the direction of the fracturing fracture propagation and the wellbore.

7. The method according to claim 2, characterized in that, Based on the sweet spot index set corresponding to multiple sub-regions to be analyzed, output fracturing implementation deployment information for the sub-regions to be analyzed, including: calculating the comprehensive sweet spot value of each sub-region to be analyzed by summing one or more sweet spot indices in the sweet spot index set; if the comprehensive sweet spot value is greater than or equal to the sweet spot threshold, then record the sub-region to be analyzed as a priority fracturing segment, and output fracturing implementation deployment information carrying the priority fracturing segment and the uniformly deployed perforation cluster of the priority fracturing segment.

8. An electronic device, characterized in that, include: Memory, processor; The memory stores computer-executable instructions; the processor executes the computer-executable instructions stored in the memory, causing the processor to perform the method as described in any one of claims 1-7.

Images