Fracturing implementation deployment optimization method and electronic equipment

Abstract

The embodiment of the invention provides a fracturing implementation deployment optimization method and electronic equipment, and relates to the technical field of fracturing transformation. The method comprises the steps of performing space division according to a well track and preset transformation information of a to-be-analyzed area, and obtaining a plurality of to-be-analyzed sub-areas; based on the constructed three-dimensional reservoir dessert distribution model, first coordinates of model grid units are obtained, the first coordinates are mapped to a current borehole local coordinate system through a preset coordinate conversion algorithm, and second coordinates of the model grid units are obtained; obtaining a dessert index set corresponding to the current to-be-analyzed sub-region through position screening; and according to the plurality of sweet spot index sets corresponding to the to-be-analyzed area, fracturing implementation deployment information is output. The fracturing influence range is divided by combining the well track and the preset transformation information, and the three-dimensional reservoir dessert distribution model is mapped to the local coordinate system of the well, so that analysis and effective identification of the fracturing exploitable potential of the far-well area are realized, and the accuracy of fracturing deployment is improved.

Description

Technical Field

[0001] The present application relates to the technical field of fracturing transformation, and in particular to a fracturing implementation deployment optimization method and electronic equipment. Background Art

[0002] In the development of unconventional oil and gas reservoirs, the wellbore trajectory serves as the basic path for horizontal well drilling and fracturing operations. It not only determines the spatial extent of the reservoir that the wellbore passes through, but also serves as the spatial reference axis for subsequent reservoir analysis and fracturing deployment. Due to the common characteristics of unconventional reservoirs such as low permeability, underdeveloped fractures, and high fracturing difficulty, multi-stage fracturing and multi-cluster perforation methods are required to effectively transform the reservoir. However, the reservoir itself is usually heterogeneous, and the formation physical properties vary dramatically, resulting in a limited spatial distribution of "sweet spots" with real high-yield potential. In order to improve the fracturing effect and reduce the risk of ineffective transformation, the sweet spot index of the reservoir is used as an important indicator of its comprehensive transformability. The analysis results of the sweet spot index determine the fracturing stage and perforation deployment locations, thereby improving the return on production capacity and resource utilization efficiency.

[0003] In existing technology, the sweet spot index is primarily derived from the interpretation of well logging curves. This method analyzes logging parameters such as porosity, permeability, brittleness, and oil saturation in the vicinity of the wellbore trajectory to generate an interpretation curve of the sweet spot index along the depth direction of the wellbore. This interpretation curve serves as the basis for fracturing stage division and perforation cluster location. In actual deployment, personnel typically select a well section with a high sweet spot index as the fracturing stage and arrange perforation clusters within this section to guide fracture propagation to the sweet spot and enhance the stimulation effect.

[0004] As can be seen, the existing technology determines fracturing deployment information mainly based on the distribution of sweet spots in the vicinity of the wellbore, failing to consider the spatial heterogeneity of the reservoir within the fracturing stimulation range. In other words, the distribution of sweet spots near the wellbore is often inconsistent with that far from the wellbore. This leads to a mismatch between the designated fracturing stages and perforation cluster locations and the actual high-yield areas, limiting the fracturing effect. Based on this, a fracturing deployment optimization method is urgently needed to address the technical problem of inaccurate fracturing deployment information. Summary of the Invention

[0005] The embodiments of the present application provide a method and electronic device for optimizing fracturing implementation and deployment, which are used to comprehensively identify the distribution of sweet spots within the fracturing transformation range, thereby improving the accuracy of fracturing implementation and deployment information.

[0006] In a first aspect, an embodiment of the present application provides a method for optimizing fracturing implementation and deployment, comprising:

[0007] According to the wellbore trajectory of the area to be analyzed and the preset transformation information corresponding to the wellbore trajectory, the area to be analyzed is spatially divided to obtain multiple sub-areas to be analyzed;

[0008] According to the trajectory sub-segment corresponding to the current sub-region to be analyzed, obtaining the current wellbore local coordinate system corresponding to the trajectory sub-segment;

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

[0010] When it is determined that the model grid unit is located in the current sub-region to be analyzed according to the second coordinate of the model grid unit, obtaining a sweet spot index of the model grid unit to obtain a sweet spot index set corresponding to the current sub-region to be analyzed;

[0011] According to the sweet spot index sets corresponding to the plurality of sub-areas to be analyzed, the fracturing implementation deployment information of the area to be analyzed is output.

[0012] In a possible implementation, spatially dividing the area to be analyzed based on the wellbore trajectory of the area to be analyzed and the preset transformation information corresponding to the wellbore trajectory to obtain multiple sub-areas to be analyzed includes:

[0013] Acquiring three-dimensional trajectory information of the wellbore trajectory, and determining a sequence of continuous coordinate points of the wellbore trajectory along a depth measurement direction based on the three-dimensional trajectory information;

[0014] Obtain one or more local wellbore coordinate systems corresponding to the wellbore trajectory, and based on the local wellbore coordinate systems and according to the transformation width in the preset transformation information, divide the continuous coordinate point sequence to obtain a plurality of trajectory subsegments;

[0015] According to the preset transformation information, a transformation length and a transformation height are obtained, and a fracturing crack expansion direction corresponding to the transformation length is obtained;

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

[0017] In a possible implementation, the step of dividing the continuous coordinate point sequence into equal intervals based on the wellbore local coordinate system and the transformation width in the preset transformation information to obtain a plurality of trajectory subsegments includes:

[0018] Screening and obtaining a plurality of continuous coordinate points belonging to the same wellbore local coordinate system, and dividing the plurality of continuous coordinate points into equal intervals according to the transformation width to obtain one or more trajectory subsegments corresponding to the wellbore local coordinate system;

[0019] Traversing the plurality of wellbore local coordinate systems, obtaining one or more trajectory subsegments corresponding to each of the wellbore local coordinate systems, so as to obtain a plurality of trajectory subsegments.

[0020] In a possible implementation, obtaining first coordinates of a plurality of model grid cells in the area to be analyzed in a geodetic coordinate system based on the constructed three-dimensional reservoir sweet spot distribution model includes:

[0021] Obtaining a constructed three-dimensional reservoir sweet spot distribution model; wherein the three-dimensional reservoir sweet spot distribution model is composed of a plurality of model grid units, and each model grid unit has a unique spatial index and attribute parameters;

[0022] A plurality of model grid units located within the area to be analyzed are screened out, and the center point coordinates of the model grid units in the geodetic coordinate system are extracted, and the center point coordinates are used as the first coordinates of the model grid units.

[0023] In a possible implementation, mapping the first coordinates to the current wellbore local coordinate system using a preset coordinate conversion algorithm to obtain second coordinates of the plurality of model grid cells includes:

[0024] 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;

[0025] According to the geodetic coordinate system and the current wellbore local coordinate system, obtaining the horizontal azimuth rotation angle of the geodetic coordinate system and the current wellbore local coordinate system;

[0026] According to the first coordinate of the model grid unit, the reference point coordinate and the horizontal azimuth rotation angle, the first coordinate is mapped to the current wellbore local coordinate system to obtain the second coordinates of the plurality of model grid units.

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

[0028] According to the first coordinate (x p ,y p , zp ), the reference point coordinates and the horizontal azimuth rotation angle, using the formula:

[0029]

[0030] Calculate and obtain the second coordinate (x' p , y' p , z' p );in, and are the horizontal and vertical coordinates of the reference point respectively; θ is the horizontal azimuth rotation angle.

[0031] In a possible implementation, determining, according to the second coordinate of the model grid unit, that the model grid unit is located in the current sub-region to be analyzed includes:

[0032] When the angle between the expansion direction of the fracturing crack and the trajectory sub-segment is 90°, if the second coordinate (x' p , y' p , z' p ) satisfies the formula:

[0033]

[0034] Then determining that the model grid unit is located in the current sub-region to be analyzed;

[0035] Among them, L w is the reconstruction width, L f is the length of the transformation, H is the height of the transformation; z w is the vertical coordinate of the left endpoint of the trajectory subsegment, and the left endpoint of the trajectory subsegment is the endpoint close to the origin of the local coordinate system of the wellbore.

[0036] In a possible implementation, determining, based on the second coordinate of the model grid unit, that the model grid unit is located in the current sub-region to be analyzed further includes:

[0037] When the angle between the fracture propagation direction and the wellbore is less than 90°, if the second coordinate (x' p , y' p , z' p ) satisfies the formula:

[0038] or,

[0039] or,

[0040]

[0041] Then determining that the model grid unit is located in the current sub-region to be analyzed;

[0042] Among them, L w is the reconstruction width, L f is the length of the transformation, H is the height of the transformation; z w is the vertical coordinate of the left endpoint of the trajectory subsegment, and the left endpoint of the trajectory subsegment is the endpoint close to the origin of the local coordinate system of the wellbore, and β is the angle between the fracturing crack propagation direction and the wellbore.

[0043] In a possible implementation, outputting the fracturing deployment information of the area to be analyzed based on the sweet spot index sets corresponding to the multiple sub-areas to be analyzed includes:

[0044] Calculate and obtain a comprehensive sweet spot value for each sub-region to be analyzed by summing up one or more sweet spot indices in the sweet spot index set;

[0045] If the comprehensive sweet spot value is greater than or equal to the sweet spot threshold, the sub-area to be analyzed is recorded as a priority fracturing section, and fracturing implementation deployment information carrying the priority fracturing section and the uniformly deployed perforation clusters in the priority fracturing section is output.

[0046] In a second aspect, an embodiment of the present application provides a device for optimizing fracturing deployment information, comprising:

[0047] A region division module is used to spatially divide the region to be analyzed according to the wellbore trajectory of the region to be analyzed and the preset transformation information corresponding to the wellbore trajectory, so as to obtain multiple sub-regions to be analyzed;

[0048] A coordinate system acquisition module is used to acquire the current wellbore local coordinate system corresponding to the trajectory subsegment according to the trajectory subsegment corresponding to the current sub-area to be analyzed;

[0049] A coordinate mapping module is configured to obtain first coordinates of a plurality of model grid cells in the area to be analyzed in the geodetic coordinate system based on the constructed three-dimensional reservoir sweet spot distribution model, and map the first coordinates to the local coordinate system of the current wellbore using a preset coordinate conversion algorithm to obtain second coordinates of the plurality of model grid cells;

[0050] a sweet spot index acquisition module, configured to acquire, based on the second coordinate of the model grid cell, the sweet spot index 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 acquire a sweet spot index set corresponding to the current sub-region to be analyzed;

[0051] The deployment information output module is used to output the fracturing implementation deployment information of the area to be analyzed based on the sweet spot index sets corresponding to the multiple sub-areas to be analyzed.

[0052] In a third aspect, an embodiment of the present application provides an electronic device, comprising: a memory, a processor;

[0053] The memory stores computer-executable instructions;

[0054] The processor executes the computer-executable instructions stored in the memory, so that the processor executes the above first aspect and / or various possible implementations of the first aspect.

[0055] In a fourth aspect, an embodiment of the present application provides a computer-readable storage medium, in which computer-executable instructions are stored. When the computer-executable instructions are executed by a processor, they are used to implement the first aspect above and / or various possible implementation methods of the first aspect.

[0056] In a fifth aspect, an embodiment of the present application provides a computer program product, including a computer program, which, when executed by a processor, implements the above first aspect and / or various possible implementation methods of the first aspect.

[0057] The embodiment of the present application provides a method and electronic device for optimizing the implementation and deployment of fracturing. By spatially dividing the area to be analyzed based on the wellbore trajectory of the area to be analyzed and the preset transformation information corresponding to the wellbore trajectory, and further obtaining multiple sub-areas to be analyzed, the accurate segmentation of the reservoir space range is achieved, so that the analysis range is more consistent with the volume area that may be affected by the fracturing cracks, ensuring that the subsequent analysis has engineering pertinence; by obtaining the trajectory sub-segment corresponding to the current sub-area to be analyzed, and establishing a local coordinate system based on the trajectory sub-segment, the coordinate conversion has a unified direction reference, and the accurate mapping of the spatial position is achieved, which improves the accuracy of the spatial correspondence between the model grid unit and the trajectory. Combined with the constructed three-dimensional reservoir sweet spot distribution model, the first coordinates of multiple model grid units in the geodetic coordinate system are obtained, and converted into the second coordinates in the current wellbore local coordinate system through a preset coordinate conversion algorithm; the model grid units are spatially screened based on the second coordinates, and the sweet spot index of the grid located in the current sub-area to be analyzed is extracted, thereby achieving a focused analysis of the reservoir quality of the local transformation area. Ultimately, by aggregating the sweet spot index sets of multiple sub-areas to be analyzed and determining the fracturing implementation deployment information for the entire area to be analyzed, it helps to improve the accuracy and rationality of fracturing stage division and perforation deployment, thereby enhancing the actual transformation efficiency and production output potential of the fracturing operation. BRIEF DESCRIPTION OF THE DRAWINGS

[0058] The accompanying drawings, which are incorporated in and constitute a part of this specification, illustrate embodiments consistent with the present application and, together with the description, serve to explain the principles of the present application.

[0059] Figure 1Schematic diagram of the fracturing transformation scenario provided for this application;

[0060] Figure 2 A schematic diagram of a flow chart of a fracturing implementation and deployment optimization method provided in an embodiment of the present application;

[0061] Figure 3 A schematic flow chart of a method for obtaining multiple sub-regions to be analyzed provided in an embodiment of the present application;

[0062] Figure 4 A schematic diagram of the planar structure of the area to be analyzed provided in an embodiment of the present application;

[0063] Figure 5 A schematic diagram of a three-dimensional structure for dividing sub-areas to be analyzed provided in an embodiment of the present application;

[0064] Figure 6 A schematic flow chart of a method for obtaining the second coordinate of a model grid unit provided in an embodiment of the present application;

[0065] Figure 7 A schematic diagram of the coordinate transformation provided in an embodiment of the present application;

[0066] Figure 8 Schematic diagram of two-dimensional coordinate transformation in different coordinate systems provided in the embodiments of the present application;

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

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

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

[0070] The above drawings illustrate specific embodiments of the present application, which will be described in more detail below. These drawings and the textual description are not intended to limit the scope of the present application in any way, but rather to illustrate the concepts of the present application to those skilled in the art by reference to specific embodiments. DETAILED DESCRIPTION

[0071] Exemplary embodiments will be described in detail herein, with examples illustrated in the accompanying drawings. In the following description, when referring to the drawings, identical numerals in different figures represent identical or similar elements, unless otherwise indicated. The embodiments described in the following exemplary embodiments are not intended to represent all embodiments consistent with the present application. Rather, they are merely examples of apparatus and methods consistent with certain aspects of the present application, as detailed in the appended claims.

[0072] First, let’s explain the terms involved in this application:

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

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

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

[0076] 3D reservoir sweet spot distribution model: This is a 3D numerical model constructed through geological modeling. Each model grid cell carries a sweet spot index that describes reservoir quality and is used to characterize the spatial distribution of high-yield potential areas.

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

[0078] Figure 1 This is a schematic diagram of the fracturing transformation scenario provided in this application. In existing industrial practices, the division of fracturing stages and the determination of perforation locations usually rely on the sweet spot index curve obtained by interpreting the well logging curve. This curve reflects the trend of geological attribute changes in the area adjacent to the wellbore. Figure 1 As shown, the sweet spot distribution generally occurs within a few meters on either side of the wellbore, corresponding only to the "near-wellbore range" (illustrated in red at location 1 and gray at location 2). However, the fracturing stimulation range encompasses not only the near-wellbore area but also, as the fracture propagates, extends further out to the wellbore. At location 1 (illustrated in the upper half of the figure), although the fracture initially initiates within the sweet spot, as it propagates farther from the wellbore, it may reach low-quality or non-sweet spots in the reservoir (illustrated in gray), resulting in wasted fracturing energy and ineffective stimulation. Location 2 (illustrated in the lower half of the figure) illustrates a different scenario: although the area adjacent to the wellbore lacks clear sweet spot characteristics, as the fracture propagates spatially, the primary control zone for the fracturing stimulation ultimately falls within a high sweet spot. In this case, deploying the fracturing strategy based on the near-wellbore sweet spot will miss the effective development area, reducing reservoir utilization efficiency.

[0079] Based on the above technical problems and needs, the inventive concept of this application is to solve the problem that the fracturing deployment in the prior art only relies on the sweet spot information in the near-well range, which is difficult to accurately reflect the reservoir heterogeneity in the actual fracturing transformation space. Specifically, this application is based on the wellbore trajectory, combined with the preset transformation parameters in the fracturing project, to spatially divide the analysis area, construct multiple sub-areas to be analyzed, so that the analysis area covers the spatial volume that may be affected by fracturing, and is not limited to the local range on both sides of the wellbore. Through this spatial division method, the geometric consistency of the analysis area of ​​the sweet spot distribution and the fracturing action area is ensured. Then, in order to achieve spatial alignment between the reservoir model and the actual transformation area, according to the local coordinate system of the wellbore, a preset coordinate conversion algorithm is used to convert multiple model grid units 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 the geological attributes, and can accurately determine whether each model grid unit falls into a sub-area to be analyzed.

[0080] After the spatial correspondence is established, the sweet spot index of the model grid cells falling within the sub-region to be analyzed is obtained and formed into a sweet spot index set for the sub-region. The sweet spot index set can fully reflect the reservoir quality that may be exhibited by the sub-region to be analyzed during the actual fracturing transformation process. Finally, this application outputs the fracturing implementation deployment information of the entire area to be analyzed based on the sweet spot index sets of multiple sub-regions, so that the fracturing segment division and deployment decisions are based on the actual reservoir space attributes, thereby improving the accuracy of fracturing and the effectiveness of reservoir transformation.

[0081] The following specific embodiments describe in detail the technical solution of the present application and how the technical solution of the present application solves the above-mentioned technical problems. The following specific embodiments can be combined with each other, and the same or similar concepts or processes may not be repeated in some embodiments. The embodiments of the present application will be described below in conjunction with the accompanying drawings.

[0082] Figure 2 A flow chart of the optimization method for fracturing implementation provided in the embodiment of the present application is shown in FIG. Figure 2 As shown, the method includes:

[0083] S21 , spatially dividing the area to be analyzed according to the wellbore trajectory of the area to be analyzed and the preset transformation information corresponding to the wellbore trajectory to obtain a plurality of sub-areas to be analyzed.

[0084] In this embodiment, the target reservoir region (i.e., the area to be analyzed) is spatially partitioned based on the wellbore trajectory and its corresponding preset stimulation information to construct multiple sub-areas to be analyzed. The wellbore trajectory refers to the actual strike path of the wellbore in three-dimensional space. It is typically composed of a series of continuous spatial coordinate points derived from drilling measurement data. These coordinate points are arranged along the wellbore sounding direction and reflect the changes in the azimuth and inclination of the wellbore at different depths. The preset stimulation information is the spatial parameters specified in the fracturing operation plan. It typically includes the stimulation width, stimulation length, and stimulation height, which correspond to the set length of the fracturing stage along the wellbore, the maximum lateral extension of the fracturing crack, and the maximum vertical extension of the fracture height, respectively. These parameters collectively define the boundaries of the three-dimensional region that the fracturing crack may affect, providing a basis for constructing analysis units. The entire area to be analyzed can be divided into several sub-areas to be analyzed. Each sub-area can be considered a representative unit of the fracturing volume and serves as a spatial carrier for subsequent steps such as sweet spot distribution identification, coordinate mapping, and attribute extraction. This partitioning method effectively aligns the wellbore trajectory with the fracturing stimulation space, improving the spatial accuracy of the overall analysis and deployment guidance capabilities.

[0085] S22, according to the trajectory sub-segment corresponding to the current sub-region to be analyzed, obtaining the current wellbore local coordinate system corresponding to the trajectory sub-segment.

[0086] In this embodiment, for the subregion to be analyzed, the corresponding trajectory subsegment is obtained. Based on this trajectory subsegment, a corresponding wellbore local coordinate system is established or invoked to provide a unified spatial reference framework for subsequent coordinate transformations and spatial attribution determination. A trajectory subsegment is a three-dimensional spatial segment formed by dividing the wellbore trajectory and reflects the actual direction of that segment of the wellbore within the three-dimensional geological model. Because wellbore trajectories often exhibit nonlinear morphology, different trajectory subsegments may belong to different wellbore local coordinate systems. However, in continuous regions where trajectory direction changes insignificantly, multiple trajectory subsegments can also share the same wellbore local coordinate system. To ensure consistency in spatial mapping, coordinate transformation, and regional determination across segments, each trajectory subsegment is associated with a wellbore local coordinate system. This wellbore local coordinate system data can be stored as an attribute of the wellbore trajectory, or a corresponding local coordinate system can be independently established for each subsegment during the trajectory subsegmentation process. The specific method can be flexibly configured based on needs, and the establishment of the local coordinate system can be performed using existing techniques and is not specifically limited here.

[0087] In the specific operation, first locate the trajectory sub-segment corresponding to the current sub-area to be analyzed, and identify the local coordinate system information of the wellbore to which the trajectory sub-segment belongs. If the trajectory sub-segment already corresponds to an existing local coordinate system, its coordinate system parameters are directly called; if it has not yet been established, a new local coordinate system is automatically constructed according to the spatial direction of the trajectory sub-segment, and further, the position of its origin in the geodetic coordinate system and the rotation relationship with the global coordinate system are recorded. Through this embodiment, a spatial projection foundation is established for each sub-area to be analyzed, and a unified expression of model coordinates and local transformation space is achieved, thereby providing a geometric reference for subsequent operations such as coordinate conversion, spatial screening and attribute mapping. This method of constructing a local coordinate system based on trajectory sub-segments improves the stability of spatial analysis 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, obtain the first coordinates of multiple model grid units in the area to be analyzed in the geodetic coordinate system, and map the first coordinates to the current wellbore local coordinate system through a preset coordinate conversion algorithm to obtain the second coordinates of the multiple model grid units.

[0089] In this embodiment, multiple model grid cells within the analysis area are first identified based on a constructed 3D reservoir sweet spot distribution model, and their spatial position information in the geodetic coordinate system (i.e., the first coordinates) is extracted. A 3D reservoir sweet spot distribution model is typically a reservoir attribute model derived through inversion of multiple geological data sources, such as seismic data, well logging data, and core analysis. Its structure consists of several regular model grid cells, each of which carries a spatial position (i.e., center point coordinates) and reservoir evaluation attributes such as a sweet spot index. To achieve geometric alignment between the geological model and the wellbore stimulation space, the spatial positions of these model grid cells must be converted from the geodetic coordinate system (typically using an absolute east-northeast-altitude coordinate system) to the local wellbore coordinate system corresponding to the current trajectory subsegment. The geodetic coordinate system reflects the global geographic location of the model within the entire reservoir, while the local wellbore coordinate system is a local spatial system constructed with the current trajectory subsegment as a reference, with its orientation aligned with the wellbore strike. Therefore, the coordinate conversion process essentially projects the global position into a local geometric system, enabling subsequent determination of which grid cells are within the current subsegment to be analyzed. Coordinate mapping is accomplished using a pre-defined coordinate conversion algorithm. After the mapping is complete, the second coordinate obtained is the position of the model grid cell in the current wellbore local coordinate system. This second coordinate reflects the spatial distribution of the model grid cell relative to the trajectory subsegment, providing a basis for determining whether it falls within the subregion to be analyzed. This embodiment establishes a geometric mapping between the reservoir geological model and the spatial structure of the well section to ensure that each data point is accurately located within the fracturing range during the analysis process.

[0090] S24 , according to 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, obtaining the sweet spot index of the model grid cell to obtain a sweet spot 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 units in the current wellbore local coordinate system are obtained. The second coordinate reflects the relative position of each model grid unit in the spatial reference system corresponding to the current trajectory sub-segment, which facilitates the judgment of whether it falls within the spatial range of the current sub-region to be analyzed. To achieve this judgment, first, a set of spatial boundary judgment conditions containing length, width and height dimensions are constructed based on the geometric boundary conditions of the sub-region in the local coordinate system. For example, the sub-region can be regarded as a rectangular cylinder or parallelepiped constructed with the trajectory sub-segment as the central axis, and its boundary is jointly defined by the transformation width, transformation length and transformation height. For each model grid unit, its second coordinate is compared one by one with the boundary conditions of the sub-region to be analyzed. If the coordinates of the model grid unit fall within the sub-region boundary range in all three directions, it can be judged that the model grid unit belongs to the current sub-region to be analyzed.

[0092] Furthermore, in order to reduce boundary misjudgment, a small boundary redundancy tolerance can be set to ensure that all grid cells with interactive possibilities are included in the judgment range. Once it is confirmed that a model grid cell belongs to the current sub-region to be analyzed, the sweet spot index corresponding to the cell in the three-dimensional reservoir sweet spot distribution model is extracted. The sweet spot indexes of all model grid cells belonging to the current sub-region will be extracted one by one and 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 the reservoir properties within the region, but also provides a data basis for subsequent comprehensive analysis and transformation optimization. By combining spatial attribution judgment and sweet spot index extraction, the mapping of three-dimensional geological model attributes to fracturing analysis units is completed. This process can ensure that fracturing deployment decisions can be based on the spatial distribution of reservoir geological properties, thereby improving the accuracy and controllability of the overall transformation.

[0093] S25 , outputting fracturing implementation deployment information of the area to be analyzed based on the sweet spot index sets corresponding to the multiple sub-areas to be analyzed.

[0094] In this embodiment, after the sweet spot index set of each sub-region to be analyzed is extracted, these data need to be summarized and analyzed to determine and output the fracturing implementation deployment information for the entire region to be analyzed. Fracturing implementation deployment information refers to the optimal judgment and deployment strategy of the fracturing section based on reservoir quality indicators, including the spatial location of the section to be fracturing, whether it has transformation value, and whether perforation clusters are deployed. Its goal is to identify the target fracturing section with high production potential through quantitative means, so as to achieve precise delivery of fracturing energy and maximize reservoir transformation efficiency. Specifically, the sweet spot index set of each sub-region to be analyzed represents the set of sweet spot attribute values ​​of all model grid cells in the sub-region. These attribute values ​​are usually 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 set in each sub-region is statistically processed. A comprehensive sweet spot value can be obtained by direct summation, mean calculation, or weighted aggregation to quantify the overall development potential of the sub-region to be analyzed.

[0095] By comprehensively assessing all sub-areas to be analyzed, comprehensive fracturing deployment information can be generated, including the spatial distribution of prioritized fracturing stages, the recommended stimulation intensity for each stage, and its relative priority relative to other well stages. This information provides a clear reference for field operations, while optimizing resource allocation, reducing ineffective stimulation efforts, and improving single-well productivity and operational efficiency.

[0096] In one embodiment, Figure 3 The flowchart of the method for obtaining multiple sub-areas to be analyzed provided in the embodiment of the present application is a specific description of an implementation method for obtaining the sub-areas to be analyzed in the above step S21. Figure 3 As shown, including:

[0097] S31, obtaining three-dimensional trajectory information of the wellbore trajectory, and determining a sequence of continuous coordinate points of the wellbore trajectory along the depth measurement direction based on the three-dimensional trajectory information;

[0098] S32, obtaining one or more wellbore local coordinate systems corresponding to the wellbore trajectory, and dividing the continuous coordinate point sequence based on the wellbore local coordinate system and the transformation width in the preset transformation information to obtain multiple trajectory subsegments;

[0099] S33, obtaining a transformation length and a transformation height according to preset transformation information, and obtaining a fracturing crack extension direction corresponding to the transformation length;

[0100] S34 , according to the stimulation length, the fracturing crack extension direction, and the stimulation height, by setting the trajectory sub-segment as the central axis, constructing a sub-region to be analyzed corresponding to the trajectory sub-segment, so as to obtain multiple sub-regions to be analyzed.

[0101] In this embodiment, the area to be analyzed is spatially divided into units based on the wellbore trajectory and preset transformation information. Specifically, three-dimensional trajectory information of the wellbore trajectory is first obtained. This three-dimensional trajectory information is typically derived from drilling measurement data, such as measurement while drilling (MWD) or logging while drilling (LWD). It contains data on the wellbore's position changes throughout the drilling process and, with depth measurement as the primary axis, forms a sequence of continuous coordinate points arranged along the wellbore extension direction. Next, one or more local wellbore coordinate systems corresponding to the wellbore trajectory are called. These local wellbore coordinate systems are used to describe the spatial directional characteristics of the wellbore in different sections. Subsequently, the continuous coordinate point sequence is divided based on the transformation width parameter provided in the preset transformation information. It is ensured that each segmented result falls within the range of the corresponding local wellbore coordinate system, thereby obtaining multiple trajectory subsegments that are geometrically continuous and directional consistent. It should be further explained that the transformation width parameter is usually greater than or equal to twice the plane size of the model grid unit in the 3D reservoir sweet spot model. For example, when the plane size of the model grid unit is 20m×20m, the transformation width parameter is at least 40m. The purpose is to ensure that there are model grid units falling within the sub-area to be analyzed.

[0102] Based on the trajectory subsegments obtained, the stimulation length and stimulation height parameters from the pre-set stimulation information are further read, corresponding to the expected lateral and vertical extensions of the fractures, respectively. Simultaneously, the fracture extension direction corresponding to the stimulation length is determined by combining the fracturing data or reservoir structural characteristics. This is typically parallel to the maximum principal stress or at a specific angle to the wellbore strike. Finally, a closed spatial unit is constructed at each trajectory subsegment's central axis within its three-dimensional location. This unit's length coincides with the trajectory subsegment, its lateral width extends according to the fracture length, and its vertical height symmetrically expands according to the fracture height, thus forming a spatial unit, the subregion to be analyzed. This subregion to be analyzed serves as the basic evaluation unit for subsequent sweet spot index projection and spatial screening, ensuring high spatial consistency between reservoir properties and fracturing deployment units. This partitioning approach not only achieves structural integration between the geological model and the wellbore trajectory but also establishes a basic unit for spatial attribute analysis within the reservoir stimulation range, providing structured geometric support for fracturing deployment decisions.

[0103] For example, Figure 4 This is a schematic diagram of the planar structure of the area to be analyzed provided in the embodiment of the present application. In order to more intuitively illustrate the relationship between the area to be analyzed and the wellbore trajectory, Figure 4Taking the figure as an example, the division of the area is further explained. The entire image is based on the three-dimensional reservoir sweet spot distribution model, and the model boundary is represented by a box, which represents the overall range covered by the constructed three-dimensional geological model. The horizontal wellbore passes through the reservoir along a specific direction and is represented by a blue line. In order to facilitate the analysis and processing related to the fracturing implementation and deployment information, it is necessary to select a computational domain (i.e., the area to be analyzed) containing the target wellbore within the three-dimensional model. As shown in the figure, the computational domain is represented by a dotted rectangle, the length of which is greater than or equal to the wellbore length and the width is approximately equal to the fracturing crack length to ensure that the entire wellbore and the fracturing influence range are included. The coordinate system of this computational domain is defined as the local wellbore coordinate system ... Figure 4 As shown, the location of the hydraulic fracture is represented by a light blue plane perpendicular to the wellbore, with the fracture center located in the middle of the wellbore. The computational domain boundary is set based on the hydraulic fracture length, wellbore length, and reservoir fracture height parameters to ensure that the area affected by the hydraulic stimulation is covered during the subsequent sweet spot unit screening and spatial positioning process.

[0104] Furthermore, in a specific embodiment, the method for obtaining multiple trajectory sub-segments in the above step S32 is further described here. Based on the above embodiment, it includes:

[0105] S321, screening and obtaining multiple continuous coordinate points belonging to the same wellbore local coordinate system, and dividing the multiple continuous coordinate points into equal intervals according to the transformation width to obtain one or more trajectory subsegments corresponding to the wellbore local coordinate system;

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

[0107] In this embodiment, the local wellbore coordinate system is a spatial reference system established for sections of the wellbore trajectory with relatively consistent orientation. It typically consists of a coordinate origin and a direction vector, and can describe the local characteristics of the wellbore direction within this section. In actual engineering, a wellbore trajectory often covers multiple sections with varying orientations, resulting in multiple local wellbore coordinate systems. Each local wellbore coordinate system corresponds to a trajectory segment (including one or more trajectory subsegments) with relatively consistent geometric orientation. First, all coordinate points in the wellbore trajectory are screened and classified according to the local wellbore coordinate system to which they belong. 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 local wellbore coordinate system, their order in the wellbore sounding direction is extracted. Without crossing coordinate systems, the coordinate point sequence is divided into equally spaced segments based on the transformation width parameter in the preset transformation information. When the cumulative distance reaches the transformation width, a complete trajectory subsegment is formed, and the start and end coordinate points of this segment are recorded. Subsequently, all local wellbore coordinate systems are traversed. For each local wellbore coordinate system, the above screening and partitioning steps are repeated to extract a set of trajectory subsegments corresponding to that coordinate system. These trajectory subsegments serve as the central axis for the spatial construction of the fracturing unit and are further used to construct the subregions to be analyzed, thereby achieving spatial integration and attribute association between the wellbore path and the reservoir geological model.

[0108] For example, Figure 5 Schematic diagram of the three-dimensional structure of the sub-areas to be analyzed provided in an embodiment of the present application. The size of the calculation domain (area 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 in the center of the calculation domain. Along the different strike positions of the wellbore trajectory, combined with the preset transformation width, the wellbore trajectory is spatially divided to obtain multiple trajectory sub-segments, and with each trajectory sub-segment as the central axis, several sub-areas to be analyzed (i.e., the vertical evaluation units shown in the figure) are constructed around it. The spatial range of each sub-area to be analyzed is represented by a transparent rectangular envelope, and the spatial size is determined by the length of the trajectory sub-segment, the length of the fracturing crack, and the crack height. Figure 5 The zoomed-in image in the upper right corner of the figure shows another type of evaluation unit (sub-area to be analyzed): an inclined evaluation unit. A vertical evaluation unit is one whose plane is perpendicular to the wellbore trajectory, meaning the fracture propagates orthogonally to the wellbore. An inclined evaluation unit, on the other hand, indicates that the fracture propagates at an angle to the wellbore trajectory. In this case, the evaluation unit configuration must be adjusted based on the angle to ensure that it accurately encompasses the primary control zone of the fracture. Specifically, the evaluation unit's long axis is parallel to the trajectory subsegment, and its wide axis is parallel to the fracture propagation direction. Figure 5This intuitively demonstrates the process of constructing sub-regions to be analyzed at different angles and spatial scales, starting from trajectory sub-segments. It also illustrates the spatial geometric relationship between the sub-regions to be analyzed, the fracturing cracks, and the wellbore trajectory in three-dimensional space. This division method effectively captures the distribution characteristics of sweet spots within the fracturing stimulation range, laying the spatial foundation for subsequent coordinate mapping, sweet spot index screening, and calculation of fracturing deployment information.

[0109] In one embodiment, a specific implementation method for obtaining the first coordinate of the model grid unit in step S23 is provided herein. Based on the above embodiment, the method includes:

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

[0111] S232 , screening out a plurality of model grid cells within the area to be analyzed, extracting the center point coordinates of the model grid cells in the geodetic coordinate system, and using the center point coordinates as first coordinates of the model grid cells.

[0112] In this embodiment, a previously constructed three-dimensional reservoir sweet spot distribution model is first used 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 the integration of multiple geological data sources, 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 that identifies its location within the entire three-dimensional model structure and also contains multiple reservoir attribute parameters, typically porosity, permeability, brittleness index, and organic matter abundance. These parameters are integrated and calculated to form a comprehensive sweet spot index. A larger sweet spot index indicates a higher fracturing potential and production capacity response capability of the reservoir at that location. 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] In order to achieve coupled calculation with the wellbore transformation space, the specific location of the model grid unit in the geographic space needs to be extracted. In this embodiment, the three-dimensional sweet spot distribution model is screened to extract all model grid units located within the boundary of the current area to be analyzed. The boundary of the area to be analyzed is usually centered on the wellbore trajectory and forms a spatial envelope in combination with the fracturing setting parameters. Only the model grid units located inside or on the boundary of this envelope will be selected as analysis objects. For each selected model grid unit, the coordinates of its geometric center point in the geodetic coordinate system are further extracted. This center point is usually determined by the geometric shape of the unit grid and serves as the representative position of the unit in subsequent coordinate transformation and spatial judgment. The extracted center point coordinates are recorded as the first coordinate of the model grid unit and used as the input parameter for mapping from the geological model to the local wellbore transformation space. In summary, this embodiment converts the reservoir geological attributes from the global expression to the local area related to the wellbore transformation by processing the three-dimensional reservoir sweet spot distribution model, thereby ensuring analysis efficiency and providing a high-precision, structured input basis for geological control in fracturing deployment.

[0114] In one embodiment, Figure 6 A schematic flow chart of a method for obtaining the second coordinate of a model grid unit provided in an embodiment of the present application. For obtaining the second coordinate of a model grid unit in the above step S23, an implementation method is provided here. Based on the above embodiment, as Figure 6 As shown, including:

[0115] S61, 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;

[0116] S62, obtaining a horizontal azimuth rotation angle of the geodetic coordinate system and the current wellbore local coordinate system according to the geodetic coordinate system and the current wellbore local coordinate system;

[0117] S63 , mapping the first coordinate to the current wellbore local coordinate system according to the first coordinate of the model grid unit, the reference point coordinate, and the horizontal azimuth rotation angle, to obtain second coordinates of the plurality of model grid units.

[0118] In this embodiment, the origin of the current wellbore local coordinate system is first determined, and the spatial coordinates of this origin in the geodetic coordinate system are obtained. These coordinates represent the absolute position of the starting point of the wellbore trajectory subsegment in a global three-dimensional coordinate system (e.g., a coordinate system with easting, northing, and elevation as axes) and are recorded as reference point coordinates. The reference point coordinates are used to translate the coordinate origin during subsequent transformations and serve as the benchmark parameters connecting the global and local systems in coordinate transformations. Secondly, the wellbore trajectory may have rotational differences with the geodetic coordinate axes in the horizontal plane, necessitating the calculation of the horizontal azimuth rotation angle between the geodetic coordinate system and the current wellbore local coordinate system. This angle is typically determined by the azimuth of the wellbore trajectory subsegment and represents the angle required to rotate counterclockwise from the geodetic coordinate system's X-axis (e.g., easting) to the X-axis (along the trajectory) of the local wellbore coordinate system. Since the Z-axes of both the geodetic coordinate system and the local wellbore coordinate system are perpendicular to the ground, meaning that the two coordinate systems are vertically aligned, the transformation can be completed by performing only a two-dimensional rotation in the horizontal plane.

[0119] After completing the parameter preparation, the first coordinate of each model grid unit (i.e., the coordinate of its center point in the geodetic coordinate system) is transformed. Exemplarily, the transformation process includes two steps: the first step is translation to align it relative to the coordinate origin; the second step is rotation. According to the horizontal azimuth rotation angle, a two-dimensional rotation matrix transformation is performed on the translated coordinates to map them to the current wellbore local coordinate system. The transformation result is the second coordinate of the model grid unit in the local space, reflecting its positional relationship relative to the wellbore trajectory direction. After the coordinate transformation, the following is obtained: Figure 7 The schematic diagram shown. Figure 7 This is a diagram illustrating the coordinate transformation structure provided in the embodiments of this application. This coordinate transformation process enables localized mapping of the reservoir's three-dimensional geological attributes. This allows subsequent operations, such as determining whether a grid falls within the subregion to be analyzed and extracting sweet spot indices, to be performed within a wellbore-dominated spatial framework, improving both the accuracy of judgment and the consistency of engineering control.

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

[0121] S431, according to the first coordinate (x p ,y p , z p ), reference point coordinates and horizontal azimuth rotation angle, using the formula:

[0122]

[0123] S432, calculate and obtain the second coordinate (x' p , y' p , z' p );in, and are the horizontal and vertical coordinates of the reference point respectively; θ is the horizontal azimuth rotation angle.

[0124] In this embodiment, in order to realize the spatial projection transformation from the earth coordinate system to the wellbore local coordinate system, coordinate transformation calculation is performed for the first coordinate of each model grid unit. Specifically, the first coordinate of each model grid unit is denoted by (x p ,y p , z p ), which represent the horizontal coordinate, vertical coordinate and vertical coordinate of the model grid unit in the geodetic coordinate system. and Represents the two-dimensional plane 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 sub-segment and the X-axis of the geodetic coordinate system, measured in a counterclockwise direction, in radians or degrees. The coordinate transformation is divided into two steps: the first step is to translate the first coordinate of the model grid cell from the origin of the geodetic coordinate system to the origin of the wellbore local coordinate system, so that it is referenced to the local coordinate system. The second step is to perform a two-dimensional rotation on the translated coordinates. The rotation uses the standard two-dimensional coordinate rotation matrix:

[0125]

[0126] The matrix transforms the coordinates on the horizontal plane while keeping the vertical coordinates unchanged, thereby obtaining the second coordinate (x' 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 is obtained. This position data is used to subsequently determine whether it falls within the subregion to be analyzed. This conversion process achieves geometric unification between the geological model and the well section stimulation space, ensuring that fracturing deployment decisions are based on the distribution of reservoir structure.

[0127] Furthermore, the derivation process of the above coordinate transformation formula is provided here to more clearly illustrate the origin of the coordinate transformation formula. Figure 8 Schematic diagram of two-dimensional coordinate transformation in different coordinate systems provided in the embodiment of this application. Figure 8 As shown in the figure, let point P be the center point of any model grid unit in the reservoir, and its coordinate in the geodetic coordinate system is (x p ,y p , zp ). Let the geodetic coordinate system xoy be the global space reference, which constructs a two-dimensional plane using unit vectors e1 and e2 as basis vectors. The local borehole coordinate system x'o'y' is the local borehole coordinate system that changes with the trajectory sub-segment direction, and let its corresponding basis vectors be e1' and e2'. According to the vector conservation law of coordinate transformation, the coordinates of point P in the two coordinate systems should satisfy the following relationship:

[0128]

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

[0130] Substituting the above unit vectors and solving them, the two-dimensional coordinate transformation formula of the center point of the model grid unit in the local coordinate system of the wellbore is:

[0131]

[0132] Further considering the absolute position of the origin of the wellbore local coordinate system in the geodetic coordinate system, the final three-dimensional coordinates of the model grid cell point P in the wellbore local coordinate system are:

[0133]

[0134] Here, Δx and Δy are the lateral and vertical offsets of the origin of the local wellbore coordinate system in the geodetic coordinate system, respectively. The z coordinate remains unchanged (i.e., the z-axis coordinate system). By combining a two-dimensional rotation matrix with a translation vector of the coordinate origin, the above formula not only ensures geometric consistency between coordinate systems but also simplifies the implementation logic of spatial transformations.

[0135] Furthermore, in a specific embodiment, a method for determining whether the model grid unit is located in the current sub-region to be analyzed in step S24 is provided herein. Based on the above embodiment, the method includes:

[0136] S2411, when the angle between the fracture propagation direction and the trajectory sub-segment is 90°, if the second coordinate of the model grid unit (x' p , y' p , z' p ) satisfies the formula:

[0137]

[0138] Then it is determined that the model grid unit is located in the current sub-region to be analyzed; where z wis the vertical coordinate of the left endpoint of the trajectory subsegment, and the left endpoint of the trajectory subsegment is the endpoint close to the origin of the local coordinate system of the wellbore; L w is the reconstruction width (corresponding to the length of the trajectory segment), L f is the stimulation length (perpendicular to the wellbore direction, corresponding to the length of the hydraulic fracture), and H is the stimulation height (i.e., the corresponding hydraulic fracture height).

[0139] In this embodiment, the expansion direction of the fracturing crack is orthogonal to the wellbore trajectory, that is, the vertical crack expansion angle β is 90°. In the local coordinate system of the wellbore, the size parameters of the spatial unit are defined, including the length along the wellbore strike direction, the width in the direction perpendicular to the fracturing, and the height in the vertical direction. At the same time, in order to facilitate the definition of the three-dimensional spatial range, the coordinates of the starting point of the trajectory sub-segment in the Z-axis direction are set as the reference for calculating the upper and lower boundaries of the spatial range. The spatial coordinates of the model grid unit in the local coordinate system are marked as (x' p , y' p , z' p ), performing a three-dimensional boundary determination on its spatial position. If the above conditions are met, it is considered to fall within the current subregion to be analyzed. The determination method provided in this embodiment achieves accurate mapping of fracturing setting parameters and reservoir distribution, providing reliable data support for fracturing stage optimization and perforation cluster deployment, and has engineering practicality for achieving efficient spatial matching.

[0140] For example, if the length of the current trajectory segment is 60m, the length of the hydraulic fracture is 100m, the fracture height is 20m, and the vertical coordinate of the trajectory segment endpoint is 2500m, then the sub-area range is: Horizontal range (along the trajectory segment direction): 0 <x' p <60m; lateral range (fracture width perpendicular to the trajectory direction): -50m <y' p <50m; vertical range (seam height range): 2490m <z' p <2510m. If the second coordinate of a model grid cell is (15, 20, 2503), all the above judgment conditions are met, so the model grid cell is located in the current sub-area to be analyzed.

[0141] In another specific embodiment, the above step S24 determines that the model grid unit is located in the current sub-region to be analyzed, and another situation judgment method is provided here. In order to deal with the situation where the expansion direction of the hydraulic fracture and the wellbore trajectory is at a non-vertical angle (that is, the angle β is less than 90°), it is necessary to adjust the original spatial screening conditions so that it can adapt to the change in the 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 rectangular parallelepiped, but a spatial italic structure after being tilted along the expansion direction of the hydraulic fracture. Therefore, the three-dimensional position determination of the model grid unit in the local coordinate system of the wellbore requires the introduction of the angle parameter β. On the basis of the above embodiment, it includes:

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

[0143]

[0144] Then the model grid unit is determined to be located in the current sub-region to be analyzed; where L w is the reconstruction width (corresponding to the length of the trajectory segment), L f is the stimulation length (perpendicular to the wellbore direction, corresponding to the length of the hydraulic fracture), H is the stimulation height (i.e., the height of the hydraulic fracture); w is the vertical coordinate of the left endpoint of the trajectory subsegment, and the left endpoint of the trajectory subsegment is the endpoint close to the origin of the local coordinate system of the wellbore, and β is the angle between the fracturing crack propagation direction and the wellbore.

[0145] In this embodiment, the inequality shows that the lateral extension range of the crack is a function of x' p The shape of the variable trapezoidal space area is controlled by the angle β. This setting is closer to the expansion space formed by the actual crack offset. And, within the 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 fracture propagation direction and the wellbore is less than 90°, if the second coordinate (x' p , y' p , z' p ) satisfies the formula:

[0147]

[0148] Then the model grid unit is determined to be located in the current sub-region to be analyzed; where L w is the reconstruction width (corresponding to the length of the trajectory segment), L fis the stimulation length (perpendicular to the wellbore direction, corresponding to the length of the hydraulic fracture), H is the stimulation height (i.e., the height of the hydraulic fracture); w is the vertical coordinate of the left endpoint of the trajectory subsegment, and the left endpoint of the trajectory subsegment is the endpoint close to the origin of the local coordinate system of the wellbore, and β is the angle between the fracturing crack propagation direction and the wellbore.

[0149] S2423, when the angle between the fracture propagation direction and the wellbore is less than 90°, if the second coordinate (x' p , y' p , z' p ) satisfies the formula:

[0150]

[0151] Then the model grid unit is determined to be located in the current sub-region to be analyzed; where L w is the reconstruction width (corresponding to the length of the trajectory segment), L f is the stimulation length (perpendicular to the wellbore direction, corresponding to the length of the hydraulic fracture), H is the stimulation height (i.e., the height of the hydraulic fracture); w is the vertical coordinate of the left endpoint of the trajectory subsegment, and the left endpoint of the trajectory subsegment is the endpoint close to the origin of the local coordinate system of the wellbore, and β is the angle between the fracturing crack propagation direction and the wellbore.

[0152] In practice, the angle β between the current trajectory subsegment 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 fracturing segments. This angle-adaptive coordinate screening mechanism enables more precise identification of model grid cells that may participate in the stimulation of fractures, thereby improving the effectiveness of sweet spot index collection and ensuring that subsequent fracturing deployment information has a clear spatial physical basis.

[0153] In one embodiment, the above step S25 outputs the fracturing deployment information of the analyzed area based on the sweet spot index sets corresponding to the multiple analyzed sub-areas. A specific implementation method is provided herein. Based on the above embodiment, it includes:

[0154] S251, calculating and obtaining a comprehensive sweet spot value for each sub-region to be analyzed by summing one or more sweet spot indices in the sweet spot index set;

[0155] S252: If the comprehensive sweet spot value is greater than or equal to the sweet spot threshold, the sub-area to be analyzed is recorded as a priority fracturing section, and fracturing implementation deployment information including the priority fracturing section and the uniformly deployed perforation clusters in the priority fracturing section is output.

[0156] In this embodiment, the sweet spot indexes of all model grid cells within the subregion to be analyzed are processed to calculate the overall sweet spot attribute level of the subregion to be analyzed. First, the sweet spot indexes of multiple previously selected model grid cells within the subregion to be analyzed are aggregated and summed to calculate a comprehensive sweet spot value for the subregion to be analyzed. This comprehensive sweet spot value is used to reflect the potential productivity level of the subregion to be analyzed during fracturing stimulation.

[0157] For example, taking the formula:

[0158]

[0159] Among them, D ijk is the sweet spot index corresponding to the model grid cell with coordinates (i, j, k); m, n, and l are the number of grid cells along the i, j, and k directions in the local coordinate system oijk, respectively. The triple summation sign indicates that the calculation involves traversing each model grid cell in the three spatial dimensions (i, j, k). This calculation result can be used as an indicator for subsequent fracturing stage screening and provides a quantitative basis for generating information for fracturing deployment.

[0160] The resulting comprehensive sweet spot value is then compared with a preset sweet spot threshold. This threshold, set by staff during the fracturing preparation phase based on historical productivity performance, reservoir evaluation criteria, and economic and technical indicators, is used to distinguish areas eligible for "prioritized fracturing" from those eligible for "postponed or excluded fracturing." 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 favorable geological and mechanical conditions, high fracturing efficiency, and high productivity response potential. Therefore, this sub-region is designated as a priority fracturing stage. For sub-regions designated as priority fracturing stages, fracturing deployment information is further output. In this embodiment, the fracturing deployment information includes the spatial layout of perforation clusters. To ensure uniform propagation of fractures within high-quality sweet spots and improve stimulation uniformity, multiple perforation clusters can be evenly distributed within the priority fracturing stage. The goal of this even distribution is to ensure that the fracture network more widely contacts the sweet spot, thereby maximizing reservoir potential. The spacing between perforation clusters can be automatically adjusted based on parameters such as fracture length, fracture height, and operation pressure to meet wellbore stability and operation safety requirements, which are not specifically defined here. This example completes the logic from sweet spot index to fracturing deployment, constructs a data-driven, reservoir heterogeneity-oriented fracturing optimization strategy, and improves the scientificity 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 properties indicate the inherent potential of a reservoir. The fracture-controlled fracability index, on the other hand, focuses on the ability of fracture-controlled techniques to transform identical or similar rock mechanical parameters and stress conditions into an effective, interconnected fracture network during hydraulic fracturing. In practice, a reservoir with a significant advantage in the sweet spot index indicates that its natural physical conditions provide a favorable foundation for fracture formation and propagation. This also means that, under good construction control, an efficient fracture network (i.e., a higher fracture-controlled fracability index) is more likely to be achieved. Therefore, measuring the fracture-controlled fracability index not only verifies the effectiveness of fracturing operations but also confirms that the reservoir advantages identified through the sweet spot index have been successfully translated into an effective pathway for increased production.

[0162] Figure 9 Schematic diagram of comparative analysis results of the implementation case provided in the embodiment of this application. In an actual application well, in order to verify the effectiveness of the fracture-controlled fracturing index in fracturing transformation, that is, the effectiveness of the sweet spot index obtained by analysis in the reservoir, a comparative analysis was carried out. Figure 9 The figure shows the difference between the fracture-controlled fracturability index profile corresponding to a horizontal well and the fracturability index profile interpreted by conventional well logging. Figure 9 In the figure, well depth is used as the horizontal axis, and the fracture-controlled fracturing index and logging interpretation fracturing index are plotted on the left and right vertical axes, respectively, reflecting the spatial variation of fracturing in different sections of the wellbore along the logging direction.

[0163] In well section 1 (2180-2480 m), both index curves show a downward trend, indicating that the distribution of reservoir sweet spots near the wellbore and within the fracturing zone is generally poor, and engineering fracturability is limited. The consistent trends of the two curves indicate that fracturability is relatively consistent between the near-wellbore and far-wellbore regions in this section. However, in well section 2 (3135-3330 m), a discrepancy emerges between the fracture-controlled fracturability index and the log-interpreted fracturability index. The fracture-controlled index profile remains relatively high (above 0.75), while the log-interpreted index shows a significant dip, reaching an overall value of approximately 0.6, indicating a trend lower than the fracture-controlled index. The key reason for this discrepancy is that the fracturing zone corresponding to well section 2 still contains a large number of engineering sweet spots within the far-wellbore region. These areas are not captured by the log curves and, therefore, are not reflected in the conventional fracturability interpretation profile. In contrast, the fracture-controlled fracturability index comprehensively considers the distribution of sweet spots within the entire sub-region that the fracturing fracture may extend to, and therefore can more accurately reflect the actual reconstruction potential of this reservoir section. The above comparison shows that the logging interpretation profile mainly reflects the reservoir quality in the area adjacent to the wellbore, lacks the ability to analyze the entire scope of the fracturing reconstruction, and may miss the sweet spots far from the wellbore, thereby affecting the accuracy of fracturing deployment. The fracture-controlled fracturability index, on the other hand, comprehensively considers the spatial properties of the reconstruction volume and the distribution of sweet spots, enhancing the engineering guidance value of the single-well profile. This case fully verifies the practicality and accuracy of the fracturing implementation and deployment optimization method proposed in this application under complex heterogeneous reservoir conditions.

[0164] Figure 10 The schematic diagram of the optimization device provided in this application is as follows: Figure 10 As shown, 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 according to the wellbore trajectory of the region to be analyzed and the preset transformation information corresponding to the wellbore trajectory to obtain multiple sub-regions to be analyzed;

[0166] A coordinate system acquisition module 102 is used to acquire the current wellbore local coordinate system corresponding to the trajectory sub-segment according to the trajectory sub-segment corresponding to the current sub-region to be analyzed;

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

[0168] The sweet spot index acquisition module 104 is configured to acquire the sweet spot index of the model grid cell according to 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 a sweet spot index set corresponding to the current sub-region to be analyzed;

[0169] The deployment information output module 105 is configured to output the fracturing deployment information of the area to be analyzed based on the sweet spot index sets corresponding to the multiple sub-areas 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 effects are similar, and are not described in detail in this embodiment.

[0171] Figure 11 This is a schematic diagram of the structure of the electronic device provided in this application. Figure 11 As shown, 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] During the specific implementation process, at least one processor 111 executes the computer-executable instructions stored in the memory 112, so that the at least one processor 111 performs the above method.

[0173] The specific implementation process of the processor 111 can be found in the above-mentioned method embodiment. Its implementation principle and technical effects are similar, and will not be repeated here in this embodiment.

[0174] In the above embodiments, it should be understood that the processor may be a central processing unit (CPU), other general-purpose processors, digital signal processors (DSP), application-specific integrated circuits (ASICs), etc. A general-purpose processor may be a microprocessor or any conventional processor. The steps of the method disclosed in the present invention may be directly executed by a hardware processor or 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.

[0176] A bus can be an Industry Standard Architecture (ISA) bus, a Peripheral Component Interconnect (PCI) bus, or an Extended Industry Standard Architecture (EISA) bus. Buses can be categorized as address buses, data buses, and control buses. For ease of illustration, the buses in the drawings of this application are not limited to just one bus or just one type of bus.

[0177] The present application also provides a computer program product, including a computer program, which implements the above method when executed by a processor.

[0178] The present application also provides a computer-readable storage medium, in which computer-executable instructions are stored. When a processor executes the computer-executable instructions, the above method is implemented.

[0179] The readable storage medium may be implemented by any type of volatile or non-volatile memory 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 may be any available medium that can be accessed by a general-purpose or special-purpose computer.

[0180] An exemplary readable storage medium is coupled to a processor so that the processor can read information from the readable storage medium and write information to the readable storage medium. Of course, the readable storage medium can also be an integral part of the processor. The processor and the readable storage medium can be located in an application specific integrated circuit (ASIC). Of course, the processor and the readable storage medium can also exist in the device as discrete components.

[0181] The division of units is merely a logical functional division; actual implementations may employ alternative divisions, such as combining or integrating multiple units or components into another system, or omitting or disabling certain features. Furthermore, any direct coupling or communication connection shown or discussed may be an indirect coupling or communication connection between devices or units, either through an interface, electrical, mechanical, or other means.

[0182] In addition, each functional unit in each embodiment of the present invention may be integrated into one processing unit, or each unit may exist physically separately, or two or more units may 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 the present invention, or the portion that contributes to the prior art, or a portion 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 for causing a computer device (which can be a personal computer, server, or network device, etc.) to execute all or part of the steps of the various embodiments of the method of the present invention. The aforementioned storage medium includes various media that can store program code, such as USB flash drives, mobile hard drives, read-only memories (ROMs), random access memories (RAMs), magnetic disks, or optical disks.

[0184] Those skilled in the art will appreciate that all or part of the steps in the above-described method embodiments can be implemented using hardware associated with 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. 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 those skilled in the art will readily identify other embodiments of the present invention after considering the specification and practicing the invention disclosed herein. The present invention is intended to cover any variations, uses, or adaptations of the present invention that follow the general principles of the present invention and include common knowledge or customary techniques in the art not disclosed herein. The present invention is not limited to the precise structure described above and illustrated in the accompanying drawings, and various modifications and variations may be made without departing from the scope thereof. The scope of the present invention is limited solely by the appended claims.

Claims

1. A method for optimizing fracturing deployment, characterized in that: include: According to the wellbore trajectory of the area to be analyzed and the preset transformation information corresponding to the wellbore trajectory, the area to be analyzed is spatially divided to obtain multiple sub-areas to be analyzed; According to the trajectory sub-segment corresponding to the current sub-region to be analyzed, obtaining the current wellbore local coordinate system corresponding to the trajectory sub-segment; Based on the constructed three-dimensional reservoir sweet spot distribution model, first coordinates of multiple model grid cells in the area to be analyzed in the geodetic coordinate system are obtained, and the first coordinates are mapped to the current wellbore local coordinate system through a preset coordinate conversion algorithm to obtain second coordinates of the multiple model grid cells; When it is determined that the model grid unit is located in the current sub-region to be analyzed according to the second coordinate of the model grid unit, obtaining a sweet spot index of the model grid unit to obtain a sweet spot index set corresponding to the current sub-region to be analyzed; According to the sweet spot index sets corresponding to the plurality of sub-areas to be analyzed, the fracturing implementation deployment information of the area to be analyzed is output.

2. The method according to claim 1, characterized in that The step of spatially dividing the area to be analyzed based on the wellbore trajectory of the area to be analyzed and the preset transformation information corresponding to the wellbore trajectory to obtain a plurality of sub-areas to be analyzed includes: Acquiring three-dimensional trajectory information of the wellbore trajectory, and determining a sequence of continuous coordinate points of the wellbore trajectory along a depth measurement direction based on the three-dimensional trajectory information; Obtain one or more local wellbore coordinate systems corresponding to the wellbore trajectory, and based on the local wellbore coordinate systems and according to the transformation width in the preset transformation information, divide the continuous coordinate point sequence to obtain a plurality of trajectory subsegments; According to the preset transformation information, a transformation length and a transformation height are obtained, and a fracturing crack expansion direction corresponding to the transformation length is obtained; According to the transformation length, the fracturing crack extension direction and the transformation height, by setting the trajectory sub-segment as the central axis, a sub-region to be analyzed corresponding to the trajectory sub-segment is constructed to obtain multiple sub-regions to be analyzed.

3. The method according to claim 2, characterized in that The method of dividing the continuous coordinate point sequence into equal intervals based on the wellbore local coordinate system and the transformation width in the preset transformation information to obtain a plurality of trajectory subsegments includes: Screening and obtaining a plurality of continuous coordinate points belonging to the same wellbore local coordinate system, and dividing the plurality of continuous coordinate points into equal intervals according to the transformation width to obtain one or more trajectory subsegments corresponding to the wellbore local coordinate system; Traversing the plurality of wellbore local coordinate systems, obtaining one or more trajectory subsegments corresponding to each of the wellbore local coordinate systems, so as to obtain a plurality of trajectory subsegments.

4. The method according to claim 1, wherein The step of obtaining first coordinates of a plurality of model grid cells in the area to be analyzed in the geodetic coordinate system based on the constructed three-dimensional reservoir sweet spot distribution model includes: Obtaining a constructed three-dimensional reservoir sweet spot distribution model; wherein the three-dimensional reservoir sweet spot distribution model is composed of a plurality of model grid units, and each model grid unit has a unique spatial index and attribute parameters; A plurality of model grid units located within the area to be analyzed are screened out, and the center point coordinates of the model grid units in the geodetic coordinate system are extracted, and the center point coordinates are used as the first coordinates of the model grid units.

5. The method according to claim 1, wherein Mapping the first coordinates to the current wellbore local coordinate system using a preset coordinate conversion algorithm to obtain second coordinates of the plurality of model grid cells includes: 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; According to the geodetic coordinate system and the current wellbore local coordinate system, obtaining the horizontal azimuth rotation angle of the geodetic coordinate system and the current wellbore local coordinate system; According to the first coordinate of the model grid unit, the reference point coordinate and the horizontal azimuth rotation angle, the first coordinate is mapped to the current wellbore local coordinate system to obtain the second coordinates of the plurality of model grid units.

6. The method according to claim 5, characterized in that The step of mapping the first coordinates of the model grid cells, the reference point coordinates, and the horizontal azimuth rotation angle to the current wellbore local coordinate system to obtain second coordinates of the plurality of model grid cells includes: According to the first coordinate (x p ,y p , z p ), the reference point coordinates and the horizontal azimuth rotation angle, using the formula: Calculate and obtain the second coordinate (x' p , y' p , z' p );in, and are the horizontal and vertical coordinates of the reference point respectively; θ is the horizontal azimuth rotation angle.

7. The method according to claim 2, characterized in that Determining, according to the second coordinate of the model grid unit, that the model grid unit is located in the current sub-region to be analyzed includes: When the angle between the expansion direction of the fracturing crack and the trajectory sub-segment is 90°, if the second coordinate (x' p , y' p , z' p ) satisfies the formula: Then determining that the model grid unit is located in the current sub-region to be analyzed; Among them, L w is the reconstruction width, L f is the length of the transformation, H is the height of the transformation; z w is the vertical coordinate of the left endpoint of the trajectory subsegment, and the left endpoint of the trajectory subsegment is the endpoint close to the origin of the local coordinate system of the wellbore.

8. The method according to claim 2, characterized in that When the angle between the fracture propagation direction and the wellbore is less than 90°, if the second coordinate (x' p , y' p , z' p ) satisfies the formula: or, or, Then determining that the model grid unit is located in the current sub-region to be analyzed; Among them, L w is the reconstruction width, L f is the length of the transformation, H is the height of the transformation; z w is the vertical coordinate of the left endpoint of the trajectory subsegment, and the left endpoint of the trajectory subsegment is the endpoint close to the origin of the local coordinate system of the wellbore, and β is the angle between the fracturing crack propagation direction and the wellbore.

9. The method according to claim 2, characterized in that Outputting fracturing deployment information of the area to be analyzed according to the sweet spot index sets corresponding to the plurality of sub-areas to be analyzed, including: Calculate and obtain a comprehensive sweet spot value for each sub-region to be analyzed by summing up 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, the sub-area to be analyzed is recorded as a priority fracturing section, and fracturing implementation deployment information carrying the priority fracturing section and the uniformly deployed perforation clusters in the priority fracturing section is output.

10. 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, so that the processor performs the method according to any one of claims 1 to 9.

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