An in-situ well spacing method and related device for deep shale gas
By acquiring reservoir parameters for geological and engineering evaluation, optimizing well spacing and target combinations, the problem of inter-well pressure channeling in deep shale gas development was solved, thereby improving the reservoir utilization range and recovery rate.
Patent Information
- Authority / Receiving Office
- CN · China
- Patent Type
- Applications(China)
- Current Assignee / Owner
- SICHUAN SHALE GAS EXPLORATION & DEV CO LTD
- Filing Date
- 2026-06-12
- Publication Date
- 2026-07-14
AI Technical Summary
In the development of deep shale gas, inter-well hydraulic channeling occurs frequently, leading to ineffective distribution of fracturing fluid and proppant, sharp drop in production of adjacent wells, and frequent production accidents such as casing damage, which seriously affect development efficiency. Existing technologies lack precise target identification and parameter optimization methods.
By acquiring reservoir geological and engineering parameters, evaluating geological and engineering sweet spots, determining platinum targets, generating initial well placement schemes within the formation, and conducting hydraulic fracturing numerical simulations, the planar well spacing and vertical target combination are optimized to generate optimal well placement parameters.
It has enabled precise quantitative selection of targets for deep shale gas reservoirs, reduced the risk of cross-flow between wells, and improved the productivity of single wells and the overall development efficiency of the platform.
Smart Images
Figure CN122383318A_ABST
Abstract
Description
Technical Field
[0001] This application relates to the field of oil and gas field development technology, and in particular to an in-layer well placement method and related apparatus for deep shale gas. Background Technology
[0002] In the exploration and development of shale gas resources, hydraulic fracturing technology is a key means to achieve reservoir stimulation and improve single-well productivity. As shale gas development gradually advances into deeper and more complex geological areas, reservoir geological conditions are becoming increasingly complex, significantly increasing the technical challenges faced by fracturing operations. Among these challenges, inter-well cross-channeling—the phenomenon where fractures connect adjacent wells or affect production in neighboring wells during fracturing—has become a significant technical bottleneck restricting the large-scale and efficient development of shale gas. Inter-well cross-channeling not only leads to ineffective distribution of fracturing fluid and proppant, reducing the stimulated volume of the target reservoir, but can also trigger production accidents such as a sharp drop in production from adjacent wells and casing damage, seriously affecting the overall development benefits of the block. In recent years, cross-channeling has become increasingly prominent in several deep shale gas development practices, and how to effectively identify and control the risk of inter-well cross-channeling has become a key technical problem urgently needing to be solved in this field.
[0003] For deep shale gas reservoirs at depths of approximately 3500–4000 m (primarily targeting high-quality Lower Paleozoic shale), located in a tectonic transition zone, the complex regional structure and relatively poor geological stability, coupled with frequent natural seismic activity, lead to frequent cross-channeling during fracturing operations. Taking this deep shale gas reservoir as an example, statistics show that out of 238 fracturing wells, 187 experienced cross-channeling, a rate as high as approximately 78.6%. With the ongoing development, the cross-channeling problem is becoming increasingly serious. Further analysis reveals that the complex geological structure and well-developed natural fractures in this deep shale gas reservoir make it highly susceptible to cross-channeling during fracturing, resulting in poor fracturing effects, low single-well productivity, and unsatisfactory overall development efficiency, severely restricting the effective utilization of shale gas resources in this area. Summary of the Invention
[0004] The purpose of this application is to provide an intra-layer well placement method and related equipment for deep shale gas, which can significantly reduce the risk of inter-well cross-flow and improve single-well productivity and overall platform development efficiency.
[0005] To achieve the above objectives, this application provides the following solution: In a first aspect, this application provides an in-layer well placement method for deep shale gas formations, comprising: The reservoir geological parameters and engineering parameters of the target block are obtained. A geological sweet spot evaluation is performed on the reservoir geological parameters to obtain a geological sweet spot evaluation result. An engineering sweet spot evaluation is performed on the engineering parameters to obtain an engineering sweet spot evaluation result. The platinum target of the target block is determined by combining the geological sweet spot evaluation result and the engineering sweet spot evaluation result. The platinum target includes a high-quality target layer segment located in the lower part and a high-quality target layer segment located in the upper part. The location parameters of the lower high-quality target layer and the upper high-quality target layer are obtained, and an initial well layout plan within the layer is generated based on the location parameters; the initial well layout plan within the layer includes the planar well spacing parameters and the longitudinal target body combination parameters of each horizontal well; The initial well placement scheme within the layer is input into a pre-constructed hydraulic fracturing numerical simulation model. Multiple different plane well spacing values and multiple different vertical target combination values are set. Multiple sets of hydraulic fracturing numerical simulations are carried out, and fracture morphology data and post-production pressure evolution data corresponding to each set of simulation results are obtained respectively. Based on the fracture morphology data and the post-production pressure evolution data, the simulation results of each group are compared and analyzed. The optimal plane well spacing is determined from multiple different plane well spacing values, and the optimal longitudinal target combination is determined from multiple different longitudinal target combination values. The optimal plane well spacing and the optimal longitudinal target combination are then output.
[0006] Optionally, the reservoir geological parameters include reservoir thickness, total organic carbon content, gas content, porosity, permeability, brittle mineral content, formation pressure coefficient, and geostress difference; The engineering parameters include formation compressibility parameters and horizontal well engineering construction parameters. The formation compressibility parameters include rock mechanics parameters and natural fracture development characteristics. The horizontal well engineering construction parameters include construction pressure, fracturing fluid compatibility, and proppant delivery conditions.
[0007] Optionally, the geological sweet spot evaluation is an evaluation of the reservoir resource potential and quality based on the reservoir geological parameters, and the reservoir sections with good gas content, high porosity, high permeability and high resource abundance are selected. The engineering sweet spot evaluation is an assessment of the feasibility and effectiveness of reservoir stimulation based on the engineering parameters, and selects reservoir sections with high brittle mineral content, well-developed natural fractures, and suitable geostress conditions for hydraulic fracturing stimulation.
[0008] Optionally, the positional parameters of the lower high-quality target layer segment and the positional parameters of the upper high-quality target layer segment are both longitudinal layer positions and spatial coordinates; The plane well spacing parameter is the distance between horizontal wells on a plane; The longitudinal target combination parameters refer to the configuration of the targets of adjacent horizontal wells in the longitudinal direction. The longitudinal target combination parameters include a first combination in which the targets of adjacent horizontal wells are located in the same high-quality target layer, a second combination in which the targets of adjacent horizontal wells are located in the lower high-quality target layer and the upper high-quality target layer respectively, and a third combination in which the targets of adjacent horizontal wells are located in another layer above the lower high-quality target layer and the upper high-quality target layer respectively.
[0009] Optionally, the construction process of the hydraulic fracturing numerical simulation model specifically includes: Obtain the actual formation thickness, physical property parameters, rock mechanics parameters, and geostress parameters of typical wells in the target block, and use the actual formation thickness, physical property parameters, rock mechanics parameters, and geostress parameters as basic data; Based on the aforementioned basic data, a three-dimensional geological model was constructed using three-dimensional geological modeling software to reconstruct the spatial distribution and geological characteristics of the reservoir. Based on the aforementioned three-dimensional geological model, a full three-dimensional hydraulic fracturing numerical simulation mechanism model is constructed using hydraulic fracturing simulation software, and this full three-dimensional hydraulic fracturing numerical simulation mechanism model is used as the hydraulic fracturing numerical simulation model. The full three-dimensional hydraulic fracturing numerical simulation mechanism model is used to simulate the artificial fracture initiation, propagation, and proppant placement process.
[0010] Optionally, the fracture morphology data includes the total length and height of the artificial fracture; the post-production pressure evolution data includes the reservoir pressure distribution and the range of inter-well pressure interference after a preset production period.
[0011] Optionally, based on the fracture morphology data and the post-production pressure evolution data, the simulation results of each group are compared and analyzed to determine the optimal plane well spacing from multiple different plane well spacing values, and the optimal longitudinal target combination is determined from multiple different longitudinal target combination values, specifically including: Multiple sets of simulation results were obtained under various different plane well spacing values and various different combinations of vertical target values; each set of simulation results included the corresponding fracture morphology data and post-production pressure evolution data; Based on multiple sets of fracture morphology data, the extension characteristics of fractures under different planar well spacing values and different longitudinal target combination values are compared and analyzed, as well as the risk of direct communication between inter-well fractures is obtained. A first comparative analysis result is obtained, and based on the first comparative analysis result, multiple candidate schemes that do not have the risk of direct communication between inter-well fractures and whose fracture extension characteristics meet preset conditions are selected. Each candidate scheme includes candidate planar well spacing values and candidate longitudinal target combination values. Based on the multiple sets of post-production pressure evolution data corresponding to the candidate plane well spacing values and the candidate longitudinal target combination values, the reservoir utilization range and inter-well interference degree under different candidate schemes are compared and analyzed to obtain a second comparative analysis result. Based on the second comparative analysis result, a preferred scheme with an inter-well interference degree lower than a preset interference threshold and a reservoir utilization degree higher than a preset utilization threshold is selected. From the preferred scheme, the corresponding plane well spacing value is determined as the optimal plane well spacing, and the corresponding longitudinal target combination value is determined as the optimal longitudinal target combination.
[0012] Optionally, after outputting the optimal planar well spacing and the optimal longitudinal target combination step, the method further includes: Based on the optimal planar well spacing and the optimal longitudinal target combination, the well deployment parameters within the layer are output; the well deployment parameters within the layer include the horizontal section orientation being perpendicular to the direction of the maximum principal stress, the horizontal section length, the planar well spacing, and the longitudinal well deployment method of alternating adjacent wells in the lower high-quality target layer and the upper high-quality target layer; Based on the well deployment parameters within the layer, corresponding fracturing process parameters are generated; the corresponding fracturing process parameters include the single-segment length of long-section multi-cluster perforations, the number of clusters in a single segment, the cluster spacing, the construction flow rate, and anti-crossing measures parameters.
[0013] In a second aspect, this application provides a computer device, including: a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the computer program to implement the intra-layer well placement method for deep shale gas as described above.
[0014] Thirdly, this application provides a computer-readable storage medium having a computer program stored thereon, which, when executed by a processor, implements the intra-layer well placement method for deep shale gas as described above.
[0015] Fourthly, this application provides a computer program product, including a computer program that, when executed by a processor, implements the intra-layer well placement method for deep shale gas as described above.
[0016] According to the specific embodiments provided in this application, this application has the following technical effects: This application provides a method and related apparatus for in-layer well placement in deep shale gas reservoirs. By acquiring reservoir geological parameters and engineering parameters of the target block, a geological sweet spot evaluation is performed on the reservoir geological parameters to obtain a geological sweet spot evaluation result. Similarly, an engineering sweet spot evaluation is performed on the engineering parameters to obtain an engineering sweet spot evaluation result. Combining the geological and engineering sweet spot evaluation results, a platinum target for the target block is determined. The platinum target includes a high-quality target segment at the bottom and a high-quality target segment at the top. This solves the problems of inaccurate identification of high-quality reservoir segments and lack of both geological and engineering basis for target selection in existing technologies. It achieves quantitative and dual-dimensional optimization of "platinum targets" in deep shale gas reservoirs, providing a scientific and unified target segment benchmark for subsequent well placement.
[0017] By acquiring the location parameters of the lower and upper high-quality target layers, an initial well placement scheme within the layer is generated based on the location parameters. The initial well placement scheme within the layer includes the planar well spacing parameters of each horizontal well and the vertical target combination parameters. This solves the problem of the lack of systematic description and parameterized expression of the differentiated configuration of vertical targets in existing well placement methods, realizes the initial structured generation of the well placement scheme within the layer, and provides a quantifiable set of input parameters for numerical simulation.
[0018] By inputting the initial well placement scheme within the layer into a pre-constructed hydraulic fracturing numerical simulation model, setting multiple different plane well spacing values and multiple different vertical target combination values, multiple sets of hydraulic fracturing numerical simulations are carried out. The fracture morphology data and post-production pressure evolution data corresponding to each set of simulation results are obtained respectively. This solves the problem in the prior art that it is impossible to make batch and quantitative predictions of the fracturing effect under different well spacing and target combinations before fracturing. It realizes parallel simulation of multiple schemes and multiple indicators of fracture morphology and post-production pressure evolution, and provides data support for parameter optimization.
[0019] Based on the fracture morphology data and the post-production pressure evolution data, the simulation results of each group are compared and analyzed. The optimal planar well spacing is determined from multiple different planar well spacing values, and the optimal longitudinal target combination is determined from multiple different longitudinal target combination values. The optimal planar well spacing and the optimal longitudinal target combination are output. This solves the problem of high pressure channeling rate and low utilization rate caused by the existing technology of determining well spacing and target combination based solely on experience in complex structures and areas with natural fracture development. It realizes dual-parameter collaborative optimization of well spacing and longitudinal target combination based on simulation data, effectively reduces the risk of direct communication between fractures between wells, and improves the reservoir utilization range and the overall recovery rate of the platform. Attached Figure Description
[0020] To more clearly illustrate the technical solutions in the embodiments of this application or the prior art, the drawings used in the embodiments will be briefly introduced below. Obviously, the drawings described below are only some embodiments of this application. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.
[0021] Figure 1 This is an application environment diagram of an in-layer well placement method for deep shale gas in Embodiment 1 of this application; Figure 2 This is a schematic flowchart of an in-layer well placement method for deep shale gas, provided in Embodiment 1 of this application. Figure 3a This is a schematic diagram of conventional well placement provided in Embodiment 2 of this application; Figure 3b This is a schematic diagram of the W-shaped well layout within a layer provided in Embodiment 2 of this application; Figure 4a This is a schematic diagram of the simulation results when the plane well spacing is 300 meters and the first combination is used, as provided in Embodiment 2 of this application; Figure 4b This is a schematic diagram of the simulation results when the plane well spacing is 300 meters and the second combination is used, as provided in Embodiment 2 of this application; Figure 4c This is a schematic diagram of the simulation results when the plane well spacing is 300 meters and the third combination is used, as provided in Embodiment 2 of this application; Figure 5a This is a schematic diagram of the simulation results when the plane well spacing is 350 meters and the first combination is used, as provided in Embodiment 2 of this application; Figure 5b This is a schematic diagram of the simulation results when the plane well spacing is 350 meters and the second combination is used, as provided in Embodiment 2 of this application; Figure 5c This is a schematic diagram of the simulation results when the plane well spacing is 350 meters and the third combination is used, as provided in Embodiment 2 of this application; Figure 6a This is a schematic diagram of the simulation results when the plane well spacing is 350 meters and the first combination is used, as provided in Embodiment 2 of this application; Figure 6b This is a schematic diagram of the simulation results when the plane well spacing is 350 meters and the second combination is used, as provided in Embodiment 2 of this application; Figure 6c This is a schematic diagram of the simulation results when the plane well spacing is 350 meters and the third combination is used, as provided in Embodiment 2 of this application; Figure 7 This is a schematic diagram of the structure of a computer device provided in an embodiment of this application. Detailed Implementation
[0022] The technical solutions of the embodiments of this application will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of this application, and not all embodiments. Based on the embodiments of this application, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of this application.
[0023] To make the above-mentioned objectives, features and advantages of this application more apparent and understandable, the application will be further described in detail below with reference to the accompanying drawings and specific embodiments.
[0024] Example 1 The in-layer well placement method for deep shale gas provided in this application embodiment can be applied to, for example... Figure 1 In the application environment shown, terminal 102 communicates with server 104 via a network. A data storage system can store the data that server 104 needs to process. The data storage system can be set up independently, integrated into server 104, or placed in the cloud or on other servers. Terminal 102 can send the reservoir geological parameters and engineering parameters of the target block to server 104. Server 104 performs geological sweetness evaluation on the reservoir geological parameters and engineering sweetness evaluation on the engineering parameters, obtaining the geological sweetness evaluation results and engineering sweetness evaluation results to determine the platinum target body of the target block; it obtains the location parameters of the lower and upper high-quality target layers within the platinum target body, and generates an initial well placement scheme within the layer based on the location parameters; it inputs the initial well placement scheme into the hydraulic fracturing numerical simulation model, conducts multiple sets of hydraulic fracturing numerical simulations, and obtains the fracture morphology data and post-production pressure evolution data corresponding to each set of simulation results; based on the fracture morphology data and post-production pressure evolution data, it compares and analyzes the simulation results of each set, and outputs the optimal planar well spacing and the optimal vertical target body combination. Server 104 can feed back the obtained optimal planar well spacing and optimal longitudinal target combination to terminal 102.
[0025] The terminal 102 can be, but is not limited to, various desktop computers, laptops, and IoT devices. The server 104 can be implemented using a standalone server or a server cluster consisting of multiple servers, or it can be a cloud server.
[0026] In one exemplary embodiment, such as Figure 2 As shown, an intra-layer well placement method for deep shale gas is provided. This method is executed by computer equipment, specifically by a terminal or server alone, or by both a terminal and a server. In this embodiment, the method is applied to... Figure 1 Taking server 104 as an example, the explanation includes the following steps 201 to 204. Wherein: Step 201: Obtain the reservoir geological parameters and engineering parameters of the target block, conduct a geological sweet spot evaluation on the reservoir geological parameters to obtain the geological sweet spot evaluation results, and conduct an engineering sweet spot evaluation on the engineering parameters to obtain the engineering sweet spot evaluation results. Combine the geological sweet spot evaluation results and the engineering sweet spot evaluation results to determine the platinum target of the target block. The platinum target includes a high-quality target layer segment located in the lower part and a high-quality target layer segment located in the upper part.
[0027] Step 202: Obtain the location parameters of the lower and upper high-quality target layers, and generate an initial well layout plan within the layer based on the location parameters; the initial well layout plan within the layer includes the planar well spacing parameters of each horizontal well and the vertical target combination parameters.
[0028] Step 203: Input the initial well layout scheme within the layer into the pre-constructed hydraulic fracturing numerical simulation model, set multiple different plane well spacing values and multiple different vertical target combination values, carry out multiple sets of hydraulic fracturing numerical simulations, and obtain the fracture morphology data and post-production pressure evolution data corresponding to each set of simulation results.
[0029] Step 204: Based on the fracture morphology data and post-production pressure evolution data, compare and analyze the simulation results of each group, determine the optimal plane well spacing from multiple different plane well spacing values, and determine the optimal longitudinal target combination from multiple different longitudinal target combination values, and output the optimal plane well spacing and the optimal longitudinal target combination.
[0030] Implementing steps 201 to 204 above will have the following beneficial effects: First, by acquiring the reservoir geological parameters and engineering parameters of the target block, a geological sweet spot evaluation is performed on the reservoir geological parameters to obtain the geological sweet spot evaluation results, and an engineering sweet spot evaluation is performed on the engineering parameters to obtain the engineering sweet spot evaluation results. By combining the geological sweet spot evaluation results and the engineering sweet spot evaluation results, the platinum target of the target block is determined. The platinum target includes a high-quality target segment located in the lower part and a high-quality target segment located in the upper part. This solves the problems of inaccurate identification of high-quality reservoir segments and lack of dual geological and engineering basis for target selection in the existing technology. It realizes the quantitative and dual-dimensional optimization of "platinum target" in deep shale gas reservoirs, and provides a scientific and unified target segment benchmark for subsequent well placement.
[0031] Second, by obtaining the location parameters of the lower and upper high-quality target segments, an initial well placement scheme within the segment is generated based on the location parameters. The initial well placement scheme within the segment includes the planar well spacing parameters of each horizontal well and the vertical target combination parameters. This solves the problem that existing well placement methods lack a systematic description and parameterized expression of the differentiated configuration of the vertical target, realizes the initial structured generation of the well placement scheme within the segment, and provides a quantifiable set of input parameters for numerical simulation.
[0032] Third, by inputting the initial well layout scheme within the formation into a pre-constructed hydraulic fracturing numerical simulation model, setting multiple different plane well spacing values and multiple different vertical target combination values, multiple sets of hydraulic fracturing numerical simulations are carried out. The fracture morphology data and post-production pressure evolution data corresponding to each set of simulation results are obtained respectively. This solves the problem in the existing technology that it is impossible to make batch and quantitative predictions of the fracturing effect under different well spacing and target combinations before fracturing. It realizes parallel simulation of multiple schemes and multiple indicators of fracture morphology and post-production pressure evolution, and provides data support for parameter optimization.
[0033] Fourth, by comparing and analyzing the simulation results of each group based on fracture morphology data and post-production pressure evolution data, the optimal planar well spacing is determined from multiple different planar well spacing values, and the optimal longitudinal target combination is determined from multiple different longitudinal target combination values. The optimal planar well spacing and the optimal longitudinal target combination are output, which solves the problem of high pressure channeling rate and low utilization rate caused by relying solely on experience to determine well spacing and target combination in complex structures and areas with natural fracture development in existing technologies. It realizes dual-parameter collaborative optimization of well spacing and longitudinal target combination based on simulation data, effectively reduces the risk of direct communication between fractures between wells, and improves the reservoir utilization range and the overall recovery rate of the platform.
[0034] Furthermore, in step 201, the reservoir geological parameters include reservoir thickness, total organic carbon content, gas content, porosity, permeability, brittle mineral content, formation pressure coefficient, and geostress difference; the engineering parameters include formation compressibility parameters and horizontal well engineering construction parameters. Formation compressibility parameters include rock mechanics parameters and natural fracture development characteristics, while horizontal well engineering construction parameters include construction pressure, fracturing fluid compatibility, and proppant delivery conditions.
[0035] Furthermore, in step 201, the geological sweet spot evaluation is an evaluation of the reservoir resource potential and quality based on reservoir geological parameters, and selects reservoir sections with good gas content, high porosity, high permeability and high resource abundance; the engineering sweet spot evaluation is an evaluation of the feasibility and effect of reservoir stimulation based on engineering parameters, and selects reservoir sections with high brittle mineral content, well-developed natural fractures and suitable geostress conditions for hydraulic fracturing stimulation.
[0036] Furthermore, in step 202, the positional parameters of the lower and upper high-quality target segments are both longitudinal stratigraphic positions and spatial coordinates; the planar well spacing parameter is the distance between horizontal wells in the plane; the longitudinal target combination parameter is the configuration of the targets of adjacent horizontal wells in the longitudinal direction. The longitudinal target combination parameter includes a first combination in which the targets of adjacent horizontal wells are located in the same high-quality target segment, a second combination in which the targets of adjacent horizontal wells are located in the lower and upper high-quality target segments respectively, and a third combination in which the targets of adjacent horizontal wells are located in another segment above the lower and upper high-quality target segments respectively.
[0037] Furthermore, the construction process of the hydraulic fracturing numerical simulation model in step 203 specifically includes: Step 2031: Obtain the actual formation thickness, physical property parameters, rock mechanics parameters, and geostress parameters of typical wells in the target block, and use the actual formation thickness, physical property parameters, rock mechanics parameters, and geostress parameters as basic data.
[0038] Step 2032: Based on the basic data, construct a three-dimensional geological model using three-dimensional geological modeling software to reconstruct the spatial distribution and geological characteristics of the reservoir.
[0039] Step 2033: Based on the three-dimensional geological model, construct a full three-dimensional hydraulic fracturing numerical simulation mechanism model using hydraulic fracturing simulation software, and use the full three-dimensional hydraulic fracturing numerical simulation mechanism model as the hydraulic fracturing numerical simulation model; the full three-dimensional hydraulic fracturing numerical simulation mechanism model is used to simulate the artificial fracture initiation, extension and proppant placement process.
[0040] Furthermore, the fracture morphology data in step 204 includes the total length and height of the artificial fractures; the post-production pressure evolution data includes the reservoir pressure distribution and the range of inter-well pressure interference after a preset production period. Based on the fracture morphology data and post-production pressure evolution data, the simulation results of each group are compared and analyzed. The optimal plane well spacing is determined from multiple different plane well spacing values, and the optimal vertical target combination is determined from multiple different vertical target combination values, specifically including: Step 2041: Obtain multiple sets of simulation results under multiple different plane well spacing values and multiple different vertical target combination values; each set of simulation results includes corresponding fracture morphology data and post-production pressure evolution data.
[0041] Step 2042: Based on multiple sets of fracture morphology data, compare and analyze the extension characteristics of fractures under different plane well spacing values and different longitudinal target combination values, as well as whether there is a risk of direct communication between fractures in different wells, to obtain the first comparative analysis result. Based on the first comparative analysis result, select multiple candidate schemes that do not have a risk of direct communication between fractures in different wells and whose fracture extension characteristics meet the preset conditions. Each candidate scheme includes candidate plane well spacing values and candidate longitudinal target combination values.
[0042] Step 2043: Based on the multiple sets of post-production pressure evolution data corresponding to the candidate planar well spacing values and candidate longitudinal target combination values, compare and analyze the reservoir utilization range and inter-well interference degree under different candidate schemes to obtain the second comparative analysis result. Based on the second comparative analysis result, select an optimal scheme where the inter-well interference degree is lower than the preset interference threshold and the reservoir utilization degree is higher than the preset utilization threshold.
[0043] Step 2044: From the preferred scheme, determine the corresponding plane well spacing value as the optimal plane well spacing, and determine the corresponding longitudinal target combination value as the optimal longitudinal target combination.
[0044] Furthermore, after the steps of outputting the optimal planar well spacing and the optimal longitudinal target combination, the process also includes: Step 205: Output the well placement parameters within the layer based on the optimal planar well spacing and the optimal longitudinal target combination. The well placement parameters within the layer include the horizontal section orientation being perpendicular to the direction of the maximum principal stress, the horizontal section length, the planar well spacing, and the longitudinal well placement method in which adjacent wells are alternately deployed in the lower and upper high-quality target layers.
[0045] Step 206: Generate supporting fracturing process parameters based on the well deployment parameters within the layer; the supporting fracturing process parameters include the single section length, single section cluster number, cluster spacing, construction flow rate, and anti-channeling measures parameters for long-section multi-cluster perforations.
[0046] Example 2 This embodiment provides an in-layer well placement method for deep shale gas. This embodiment uses a deep shale gas block (buried at a depth of approximately 3500m~4000m, the target layer being high-quality shale with complex geological structure and relatively poor geological stability) as an example for detailed explanation.
[0047] Step 1: Optimization of target layer and platinum target.
[0048] Step S1: Obtain the reservoir geological parameters and engineering parameters of the target block; conduct a geological sweet spot evaluation on the reservoir geological parameters to obtain the geological sweet spot evaluation result; conduct an engineering sweet spot evaluation on the engineering parameters to obtain the engineering sweet spot evaluation result; combine the geological sweet spot evaluation result and the engineering sweet spot evaluation result to determine the platinum target of the target block; the platinum target includes a high-quality target layer segment located in the lower part and a high-quality target layer segment located in the upper part.
[0049] Specifically, the reservoir geological parameters include reservoir thickness, total organic carbon content, gas content, porosity, permeability, brittle mineral content, formation pressure coefficient, and geostress differential. The engineering parameters include formation compressibility parameters and horizontal well construction parameters. The formation compressibility parameters include rock mechanics parameters and natural fracture development characteristics. The horizontal well construction parameters include construction pressure, fracturing fluid compatibility, and proppant delivery conditions.
[0050] The geological sweet spot evaluation is an assessment of the reservoir's resource potential and quality based on the reservoir geological parameters, selecting reservoir sections with good gas content, high porosity, high permeability, and high resource abundance. Specifically, based on well logging analysis of the relationship between reservoir lithology, physical properties, electrical properties, and gas content, the optimal sections with the best total organic carbon content, porosity, gas content, and gas saturation parameters are selected.
[0051] The engineering sweet spot evaluation is an assessment of the feasibility and effectiveness of reservoir stimulation based on the aforementioned engineering parameters, prioritizing reservoir sections with high brittle mineral content, well-developed natural fractures, and suitable geostress conditions for hydraulic fracturing. Specifically, sections with high brittle mineral content, low clay content, small difference coefficient of horizontal principal stress, and high Young's modulus are preferred for their compressibility.
[0052] Based on the combined geological and engineering evaluation results, the platinum target for the development zone was determined. In this embodiment, the first to second sub-layers are preferred as the core target segment. Specifically, the lower high-quality target layer segment is located in the lower region of the first to second sub-layers; the upper high-quality target layer segment is located in the upper region of the second sub-layer. The longitudinal distance between the lower and upper high-quality target layer segments is optimized to 3 meters.
[0053] Step 2: Generate the initial well layout scheme within the layer.
[0054] Step S2: Obtain the location parameters of the lower high-quality target layer and the upper high-quality target layer, and generate an initial well layout plan within the layer based on the location parameters; the initial well layout plan within the layer includes the planar well spacing parameters of each horizontal well and the longitudinal target body combination parameters.
[0055] Specifically, the positional parameters of the lower high-quality target layer and the upper high-quality target layer are both longitudinal stratigraphic and spatial coordinates. The planar well spacing parameter is the distance between horizontal wells in a plane. The longitudinal target combination parameter is the longitudinal configuration of the targets of adjacent horizontal wells.
[0056] After the target selection is completed, based on the lower high-quality target layer and the upper high-quality target layer determined in step S1, within the same development platform, without changing the horizontal well deployment orientation, the targets of adjacent horizontal wells are configured differently in the vertical direction: the targets of some horizontal wells are placed in the lower high-quality target layer, and the targets of adjacent horizontal wells are placed in the upper high-quality target layer, forming a three-dimensional well network pattern of alternating vertical and staggered horizontal, that is, the W-shaped well layout pattern within the layer.
[0057] As shown in Figure 3. Figure 3a This is a schematic diagram of a conventional well layout, where the targets of adjacent horizontal wells are all located in the same high-quality target layer. Figure 3b This is a schematic diagram of the W-shaped well layout within the layer in this embodiment. The targets of adjacent horizontal wells are located in the lower high-quality target layer and the upper high-quality target layer, respectively, forming a longitudinally alternating W-shaped trajectory.
[0058] Step 3: Optimization of key parameters based on numerical simulation.
[0059] Step S3: Input the initial well layout scheme within the layer into the pre-constructed hydraulic fracturing numerical simulation model, set multiple different plane well spacing values and multiple different longitudinal target combination values, carry out multiple sets of hydraulic fracturing numerical simulations, and obtain the fracture morphology data and post-production pressure evolution data corresponding to each set of simulation results.
[0060] Specifically, the construction process of the hydraulic fracturing numerical simulation model includes: Step S31: Obtain the actual formation thickness, physical property parameters, rock mechanical parameters, and geostress parameters of typical wells in the target block, and use the actual formation thickness, physical property parameters, rock mechanical parameters, and geostress parameters as basic data; Step S32: Based on the aforementioned basic data, construct a three-dimensional geological model using three-dimensional geological modeling software to reconstruct the spatial distribution and geological characteristics of the reservoir; Step S33: Based on the three-dimensional geological model, construct a full three-dimensional hydraulic fracturing numerical simulation mechanism model using hydraulic fracturing simulation software, and use the full three-dimensional hydraulic fracturing numerical simulation mechanism model as the hydraulic fracturing numerical simulation model; the full three-dimensional hydraulic fracturing numerical simulation mechanism model is used to simulate the artificial fracture initiation, extension and proppant placement process.
[0061] In this embodiment, the fracture morphology data includes the total length and height of the artificial fracture; the post-production pressure evolution data includes the reservoir pressure distribution and the range of inter-well pressure interference after a preset production period.
[0062] This embodiment sets three planar well spacing values (300 meters, 350 meters, and 400 meters) and three longitudinal target combination values, as follows: First combination (combination A): The targets of adjacent horizontal wells are located in the same high-quality target layer segment, that is, the upper and lower target layers are both in the lower region of the first sub-layer to the second sub-layer, with a longitudinal spacing of 0 meters; The second combination (combination B): the targets of adjacent horizontal wells are located in the lower high-quality target layer section and the upper high-quality target layer section respectively, that is, the lower target is the lower region from the first sub-layer to the second sub-layer, and the upper target is the upper region of the second sub-layer, with a longitudinal spacing of 3 meters; The third combination (combination C): the targets of adjacent horizontal wells are located in another layer above the lower high-quality target layer and the upper high-quality target layer, respectively. That is, the lower target is the lower region of the first sub-layer to the second sub-layer, and the upper target is the third sub-layer, with a longitudinal spacing of 7 meters.
[0063] Based on the aforementioned values for the planar well spacing and the longitudinal target combination, multiple sets of hydraulic fracturing numerical simulations were conducted to compare and analyze the fracturing effects of different schemes. The simulations showed that the hydraulic fractures after fracturing were distributed in a star-shaped pattern, with a total fracture length of approximately 290 to 300 meters and a fracture height of approximately 16 to 18 meters.
[0064] Step 4: Comparison and analysis of simulation results and determination of optimal parameters.
[0065] Step S4: Based on the fracture morphology data and the post-production pressure evolution data, compare and analyze the simulation results of each group, determine the optimal plane well spacing from multiple different plane well spacing values, and determine the optimal longitudinal target combination from multiple different longitudinal target combination values, and output the optimal plane well spacing and the optimal longitudinal target combination.
[0066] Specifically, this step includes: Step S41: Obtain multiple sets of simulation results under multiple different plane well spacing values and multiple different vertical target body combination values; each set of simulation results includes the corresponding fracture morphology data and the post-production pressure evolution data; Step S42: Based on multiple sets of fracture morphology data, compare and analyze the fracture extension characteristics and the risk of direct communication between fractures under different plane well spacing values and different longitudinal target combination values to obtain a first comparative analysis result. Based on the first comparative analysis result, select multiple candidate schemes that do not have the risk of direct communication between fractures and whose fracture extension characteristics meet the preset conditions. Each candidate scheme includes a candidate plane well spacing value and a candidate longitudinal target combination value. Step S43: Based on the multiple sets of post-production pressure evolution data corresponding to the candidate plane well spacing values and the candidate longitudinal target combination values, compare and analyze the reservoir utilization range and inter-well interference degree under different candidate schemes to obtain a second comparative analysis result. Based on the second comparative analysis result, select an optimal scheme where the inter-well interference degree is lower than the preset interference threshold and the reservoir utilization degree is higher than the preset utilization threshold. Step S44: From the preferred scheme, determine the corresponding plane well spacing value as the optimal plane well spacing, and determine the corresponding longitudinal target combination value as the optimal longitudinal target combination.
[0067] The following section provides a detailed explanation of this step based on specific simulation results.
[0068] (a) Simulation results of 300-meter plane well spacing.
[0069] When the well spacing is 300 meters, numerical simulations of fracture morphology and post-production pressure evolution were conducted for the three longitudinal target combinations mentioned above, and the results are shown in Figure 4. In Figure 4, the left figure is the longitudinal distribution of the single reservoir coefficient of the model. The simulated artificial fracture is a star-shaped fracture. The fracture color represents the distribution of proppant concentration. The warm-colored area is the range of the propped fracture, and the blue area is the range of the hydraulic fracture. The right figure is the prediction map of the post-production pressure relief range, predicting the situation after 20 years of production. The pressure reduction in the artificial fracture area is the largest. The matrix pressure near the fracture is slightly reduced, while the matrix pressure in the more distant part remains unchanged.
[0070] Figure 4a This represents the simulation results when the plane well spacing is 300 meters and the first combination is used, that is, both the upper and lower target bodies are the first small layer; Figure 4b This represents the simulation results when the plane well spacing is 300 meters and the second combination is used, that is, the lower target is the lower region from the first sub-layer to the second sub-layer, the upper target is the upper region of the second sub-layer, and the longitudinal distance between the two sets of targets is 3 meters; Figure 4c The simulation results show that the plane well spacing is 300 meters and the third combination is used. That is, the lower target is the lower region from the first sub-layer to the second sub-layer, the upper target is the third sub-layer, and the longitudinal distance between the two sets of targets is 7 meters.
[0071] Numerical simulation results of fracture morphology show that when all targets are located in the lower target layer, the fracture length is close to the well spacing, and the probability of inter-well hydraulic channeling is relatively high. When a three-dimensional development method is used, with the upper target layer placed above the second or third sub-layer, the longest peaks of the fracture morphology are staggered, which can reduce the risk of inter-well hydraulic channeling to some extent. However, post-production pressure numerical simulation results show that regardless of which sub-layer the three-dimensional development target is located in, the overlap of the depressurization area is large, resulting in significant inter-well hydraulic channeling and production interference. Therefore, a planar well spacing of 300 meters is not conducive to fracturing operations.
[0072] (ii) Simulation results of 350-meter plane well spacing.
[0073] When the plane well spacing is 350 meters, numerical simulations of fracture morphology and post-production pressure evolution are carried out for the three longitudinal target combinations mentioned above, and the results are shown in Figure 5. Figure 5a This represents the simulation results when the plane well spacing is 350 meters and the first combination is used; Figure 5b This represents the simulation results when the plane well spacing is 350 meters and the second combination is used, with a longitudinal distance of 3 meters between the two sets of targets; Figure 5c This represents the simulation results when the plane well spacing is 350 meters and the third combination is used, with a longitudinal distance of 7 meters between the two sets of targets.
[0074] Numerical simulation results of fracture morphology show that, regardless of which sublayer the upper target is located in, the longest peak of the fracture morphology is less than the 350-meter plane well spacing, which can reduce the risk of inter-well pressure channeling to a certain extent. Based on the post-production pressure distribution range, when the target positions are all located in the lower region of the first to second sublayers, the pressure relief area overlaps significantly; when the upper target is located in the upper part of the second sublayer, the pressure relief area overlaps less, and the upper well can also stimulate the high-quality reservoirs in the first to second sublayers; when the upper target is located in the third sublayer, the high-quality reservoirs in the first and second sublayers are not sufficiently stimulated, resulting in insufficient utilization of single-well reserves.
[0075] (III) Simulation results of 400-meter plane well spacing.
[0076] When the plane well spacing is 400 meters, numerical simulations of fracture morphology and post-production pressure evolution are carried out for the above three longitudinal target combinations, and the results are shown in Figure 6. Figure 6a This represents the simulation results when the plane well spacing is 400 meters and the first combination is used; Figure 6b This represents the simulation results when the plane well spacing is 400 meters and the second combination is used, with a longitudinal distance of 3 meters between the two sets of targets; Figure 6c This represents the simulation results when the plane well spacing is 400 meters and the third combination is used, with a longitudinal distance of 7 meters between the two sets of targets.
[0077] Numerical simulation results of fracture morphology show that the longest peak of the fracture is less than the 400-meter plane well spacing, which can effectively reduce the risk of inter-well pressure channeling. According to the post-production pressure distribution range, the production interference between each target location is small, but the inter-well reserves are not fully utilized, resulting in a waste of inter-well reserves and a relatively poor three-dimensional development effect.
[0078] (iv) Comprehensive comparison and determination of optimal parameters.
[0079] The results of comparing the fracture morphology, post-production pressure evolution data, final recoverable reserves of a single well, cumulative production of the platform, and overall recovery rate of each scheme are shown in Table 1.
[0080] Table 1 Comparison of Development Indicators for Different Well Spacings and Target Locations
[0081] Based on comprehensive comparative analysis, the main conclusions are as follows: When the plane well spacing is 300 meters, regardless of the longitudinal offset, the overlap range of the post-production depressurization area is relatively large, resulting in a high risk of inter-well pressure cross-flow and production interference.
[0082] When the plane well spacing is 400 meters, the risk of inter-well cross-flow is low, but the inter-well reserves are not fully utilized, and the platform recovery rate decreases significantly.
[0083] When the plane well spacing is 350 meters and the second combination is used (i.e., the longitudinal spacing is 3 meters, the lower target is located in the lower region from the first sub-layer to the second sub-layer, and the upper target is located in the upper region of the second sub-layer), the longest half-fracture length is approximately 300 meters. A plane well spacing of less than 350 meters can effectively prevent direct communication between fractures; the post-production depressurization areas partially overlap but not excessively, achieving "connection without cross-contamination"; the final recoverable reserves of a single well are 1.19 × 10⁻⁶. 8 Cubic meters, the platform's cumulative output is 5.95 × 10 8 The volume was 1 cubic meter, and the recovery rate was 16.14%, both of which are at a relatively good level.
[0084] Therefore, the optimal parameters are determined as follows: the optimal plane well spacing is 350 meters, and the optimal longitudinal target combination is the second combination, that is, the lower target is located in the lower region from the first sub-layer to the second sub-layer, the upper target is located in the upper region of the second sub-layer, and the longitudinal spacing between the upper and lower targets is 3 meters.
[0085] Step 5: Deployment of wells within the layer and supporting processes.
[0086] Step S5: Output the well placement parameters within the layer based on the optimal planar well spacing and the optimal longitudinal target combination; the well placement parameters within the layer include the horizontal section orientation being perpendicular to the direction of the maximum principal stress, the horizontal section length, the planar well spacing, and the longitudinal well placement method in which adjacent wells are alternately deployed in the lower high-quality target layer and the upper high-quality target layer.
[0087] In this embodiment, based on the above optimized parameters, a complete in-layer well placement implementation scheme is formed: Orientation of the horizontal segment: perpendicular to the direction of the maximum principal stress, in order to facilitate the formation of a mesh; Horizontal section length: designed to be 1800 to 2000 meters; Spacing between wells in planar plane: 350 meters; Vertical well placement method: Adjacent horizontal wells within the same development platform are alternately deployed in the lower high-quality target layer section (i.e., the lower region from the first sub-layer to the second sub-layer) and the upper high-quality target layer section (i.e., the upper region of the second sub-layer), with a W-shaped trajectory in the profile.
[0088] Step S6: Generate matching fracturing process parameters based on the well deployment parameters within the layer; the matching fracturing process parameters include the single-segment length of the long-section multi-cluster perforation, the number of clusters in a single segment, the cluster spacing, the construction flow rate, and anti-channeling measures parameters.
[0089] In this embodiment, to complement the W-shaped well layout within the formation and further reduce the risk of cross-channeling between wells, a differentiated anti-cross-channeling fracturing process is adopted: Long-segment multi-cluster perforation: single segment length is 70 meters, single segment number of clusters is 8 to 11, and cluster spacing is 7 to 10 meters; Construction flow rate: 18 to 20 cubic meters per minute for the main body; Anti-channeling measures include: pre-positioning a high-concentration sand plug section, phased pump shutdown and reversal, and fiber-carrying injection.
[0090] Through the above steps, this embodiment achieves dual-parameter synergistic optimization of planar well spacing and vertical target combination in deep shale gas reservoirs, effectively reducing the risk of inter-well pressure channeling, improving reservoir utilization and overall platform development efficiency.
[0091] In one exemplary embodiment, a computer device is provided, which may be a server or a terminal, and its internal structure diagram may be as follows. Figure 7As shown, this computer device includes a processor, memory, input / output (I / O) interfaces, and a communication interface. The processor, memory, and I / O interfaces are connected via a system bus, and the communication interface is also connected to the system bus via the I / O interfaces. The processor provides computational and control capabilities. The memory includes non-volatile storage media and internal memory. The non-volatile storage media stores the operating system, computer programs, and a database. The internal memory provides the environment for the operation of the operating system and computer programs in the non-volatile storage media. The database stores and processes data. The I / O interfaces are used for exchanging information between the processor and external devices. The communication interface is used for communicating with external terminals via a network. When the computer program is executed by the processor, it implements an in-layer well placement method for deep shale gas.
[0092] Figure 7 The structures shown are merely block diagrams of some structures related to the present application and do not constitute a limitation on the computer device to which the present application is applied. Specific computer devices may include more or fewer components than shown in the figures, or combine certain components, or have different component arrangements. In an exemplary embodiment, a computer device is provided, including a memory and a processor. The memory stores a computer program, and the processor executes the computer program to implement the steps in the above-described method embodiments.
[0093] In one exemplary embodiment, a computer-readable storage medium is provided storing a computer program that, when executed by a processor, implements the steps in the above-described method embodiments.
[0094] In one exemplary embodiment, a computer program product is provided, including a computer program that, when executed by a processor, implements the steps in the above-described method embodiments.
[0095] It should be noted that the user information (including but not limited to user device information, user personal information, etc.) and data (including but not limited to data used for analysis, data stored, data displayed, etc.) involved in this application are all information and data authorized by the user or fully authorized by all parties, and the collection, use and processing of related data must comply with relevant regulations and be authorized by the owner of the corresponding device.
[0096] Those skilled in the art will understand that all or part of the processes in the above embodiments can be implemented by a computer program instructing related hardware. The computer program can be stored in a non-volatile computer-readable storage medium. When executed, the computer program can include the processes of the embodiments described above. Any references to memory, databases, or other media used in the embodiments provided in this application can include at least one of non-volatile and volatile memory. Non-volatile memory can include read-only memory (ROM), magnetic tape, floppy disk, flash memory, optical memory, high-density embedded non-volatile memory, resistive random access memory (ReRAM), magnetic random access memory (MRAM), ferroelectric random access memory (FRAM), phase change memory (PCM), graphene memory, etc. Volatile memory can include random access memory (RAM) or external cache memory, etc. By way of illustration and not limitation, RAM can take many forms, such as Static Random Access Memory (SRAM) or Dynamic Random Access Memory (DRAM).
[0097] The databases involved in the embodiments provided in this application may include at least one type of relational database and non-relational database. Non-relational databases may include, but are not limited to, blockchain-based distributed databases. The processors involved in the embodiments provided in this application may be general-purpose processors, central processing units, graphics processing units, digital signal processors, programmable logic devices, quantum computing-based data processing logic devices, etc., and are not limited to these.
[0098] The technical features of the above embodiments can be combined in any way. For the sake of brevity, not all possible combinations of the technical features in the above embodiments are described. However, as long as there is no contradiction in the combination of these technical features, they should be considered to be within the scope of this specification.
[0099] This document uses specific examples to illustrate the principles and implementation methods of this application. The descriptions of the above embodiments are only for the purpose of helping to understand the methods and core ideas of this application. Furthermore, those skilled in the art will recognize that, based on the ideas of this application, there will be changes in the specific implementation methods and application scope. Therefore, the content of this specification should not be construed as a limitation of this application.
Claims
1. A method for in-layer well placement in deep shale gas formations, characterized in that, The method includes: The reservoir geological parameters and engineering parameters of the target block are obtained. A geological sweet spot evaluation is performed on the reservoir geological parameters to obtain a geological sweet spot evaluation result. An engineering sweet spot evaluation is performed on the engineering parameters to obtain an engineering sweet spot evaluation result. The platinum target of the target block is determined by combining the geological sweet spot evaluation result and the engineering sweet spot evaluation result. The platinum target includes a high-quality target layer segment located in the lower part and a high-quality target layer segment located in the upper part. The location parameters of the lower high-quality target layer and the upper high-quality target layer are obtained, and an initial well layout plan within the layer is generated based on the location parameters; the initial well layout plan within the layer includes the planar well spacing parameters and the longitudinal target body combination parameters of each horizontal well; The initial well placement scheme within the layer is input into a pre-constructed hydraulic fracturing numerical simulation model. Multiple different plane well spacing values and multiple different vertical target combination values are set. Multiple sets of hydraulic fracturing numerical simulations are carried out, and fracture morphology data and post-production pressure evolution data corresponding to each set of simulation results are obtained respectively. Based on the fracture morphology data and the post-production pressure evolution data, the simulation results of each group are compared and analyzed. The optimal plane well spacing is determined from multiple different plane well spacing values, and the optimal longitudinal target combination is determined from multiple different longitudinal target combination values. The optimal plane well spacing and the optimal longitudinal target combination are then output.
2. The method for in-layer well placement for deep shale gas as described in claim 1, characterized in that, The reservoir geological parameters include reservoir thickness, total organic carbon content, gas content, porosity, permeability, brittle mineral content, formation pressure coefficient, and geostress difference. The engineering parameters include formation compressibility parameters and horizontal well engineering construction parameters. The formation compressibility parameters include rock mechanics parameters and natural fracture development characteristics. The horizontal well engineering construction parameters include construction pressure, fracturing fluid compatibility, and proppant delivery conditions.
3. The method for in-layer well placement for deep shale gas as described in claim 1, characterized in that, The geological sweet spot evaluation is an assessment of the reservoir's resource potential and quality based on the reservoir geological parameters, and selects reservoir sections with good gas content, high porosity, high permeability, and high resource abundance. The engineering sweet spot evaluation is an assessment of the feasibility and effectiveness of reservoir stimulation based on the engineering parameters, and selects reservoir sections with high brittle mineral content, well-developed natural fractures, and suitable geostress conditions for hydraulic fracturing stimulation.
4. The method for in-layer well placement for deep shale gas as described in claim 1, characterized in that, The positional parameters of the lower high-quality target layer and the upper high-quality target layer are both longitudinal layer and spatial coordinates; The plane well spacing parameter is the distance between horizontal wells on a plane; The longitudinal target combination parameters refer to the configuration of the targets of adjacent horizontal wells in the longitudinal direction. The longitudinal target combination parameters include a first combination in which the targets of adjacent horizontal wells are located in the same high-quality target layer, a second combination in which the targets of adjacent horizontal wells are located in the lower high-quality target layer and the upper high-quality target layer respectively, and a third combination in which the targets of adjacent horizontal wells are located in another layer above the lower high-quality target layer and the upper high-quality target layer respectively.
5. The method for in-layer well placement for deep shale gas according to claim 1, characterized in that, The construction process of the hydraulic fracturing numerical simulation model specifically includes: Obtain the actual formation thickness, physical property parameters, rock mechanics parameters, and geostress parameters of typical wells in the target block, and use the actual formation thickness, physical property parameters, rock mechanics parameters, and geostress parameters as basic data; Based on the aforementioned basic data, a three-dimensional geological model was constructed using three-dimensional geological modeling software to reconstruct the spatial distribution and geological characteristics of the reservoir. Based on the aforementioned three-dimensional geological model, a full three-dimensional hydraulic fracturing numerical simulation mechanism model is constructed using hydraulic fracturing simulation software, and this full three-dimensional hydraulic fracturing numerical simulation mechanism model is used as the hydraulic fracturing numerical simulation model. The full three-dimensional hydraulic fracturing numerical simulation mechanism model is used to simulate the artificial fracture initiation, propagation, and proppant placement process.
6. The method for in-layer well placement for deep shale gas according to claim 1, characterized in that, The fracture morphology data includes the total length and height of the artificial fracture; the post-production pressure evolution data includes the reservoir pressure distribution and the range of inter-well pressure interference after a preset production period.
7. The method for in-layer well placement for deep shale gas according to claim 1, characterized in that, Based on the fracture morphology data and the post-production pressure evolution data, the simulation results of each group were compared and analyzed. The optimal plane well spacing was determined from multiple different plane well spacing values, and the optimal longitudinal target combination was determined from multiple different longitudinal target combination values, specifically including: Multiple sets of simulation results were obtained under various different plane well spacing values and various different combinations of vertical target values; each set of simulation results included the corresponding fracture morphology data and post-production pressure evolution data; Based on multiple sets of fracture morphology data, the extension characteristics of fractures under different planar well spacing values and different longitudinal target combination values are compared and analyzed, as well as the risk of direct communication between inter-well fractures is obtained. A first comparative analysis result is obtained, and based on the first comparative analysis result, multiple candidate schemes that do not have the risk of direct communication between inter-well fractures and whose fracture extension characteristics meet preset conditions are selected. Each candidate scheme includes candidate planar well spacing values and candidate longitudinal target combination values. Based on the multiple sets of post-production pressure evolution data corresponding to the candidate plane well spacing values and the candidate longitudinal target combination values, the reservoir utilization range and inter-well interference degree under different candidate schemes are compared and analyzed to obtain a second comparative analysis result. Based on the second comparative analysis result, a preferred scheme with an inter-well interference degree lower than a preset interference threshold and a reservoir utilization degree higher than a preset utilization threshold is selected. From the preferred scheme, the corresponding plane well spacing value is determined as the optimal plane well spacing, and the corresponding longitudinal target combination value is determined as the optimal longitudinal target combination.
8. The method for in-layer well placement for deep shale gas according to claim 1, characterized in that, After outputting the optimal planar well spacing and the optimal longitudinal target combination, the method further includes: Based on the optimal planar well spacing and the optimal longitudinal target combination, the well deployment parameters within the layer are output; the well deployment parameters within the layer include the horizontal section orientation being perpendicular to the direction of the maximum principal stress, the horizontal section length, the planar well spacing, and the longitudinal well deployment method of alternating adjacent wells in the lower high-quality target layer and the upper high-quality target layer; Based on the well deployment parameters within the layer, corresponding fracturing process parameters are generated; the corresponding fracturing process parameters include the single-segment length of long-section multi-cluster perforations, the number of clusters in a single segment, the cluster spacing, the construction flow rate, and anti-crossing measures parameters.
9. A computer device, comprising: A memory, a processor, and a computer program stored in the memory and capable of running on the processor, characterized in that the processor executes the computer program to implement the intra-layer well placement method for deep shale gas as described in any one of claims 1-8.
10. A computer-readable storage medium having a computer program stored thereon, characterized in that, When executed by a processor, the computer program implements the intra-layer well placement method for deep shale gas as described in any one of claims 1-8.