Method and device for predicting productivity of shale gas well in pressure channeling well group

Abstract

The invention relates to the field of energy development, in particular to a method and device for predicting the productivity of a shale gas well in a pressure channeling well group. The method comprises the steps that casing deformation conditions and pressure channeling related data in a single-section shale gas well are obtained, and therefore the pressure channeling influence borne by each shale gas well is comprehensively considered in a pressure channeling well group; according to the casing deformation condition, a productivity prediction result considering casing deformation is obtained, then the productivity prediction result considering pressure channeling is calculated, and if pressure channeling does not occur, the productivity prediction result considering casing deformation is a final productivity prediction result; if pressure channeling occurs, pressure channeling related data needs to be subjected to grading and classification evaluation, the pressure channeling degree of the single-section shale gas well is obtained, and then a final productivity prediction result is obtained in combination with natural fracture distribution information. The productivity prediction in the well completion stage of the pressure channeling well group of the shale gas well is carried out by taking the well group as a unit, guidance is provided for optimization of a gas well development strategy, and the labor cost and the time cost are greatly saved.

Description

Technical Field

[0001] This specification relates to the field of energy development, and in particular to a method and apparatus for predicting the production capacity of shale gas wells in a pressure-driven well group. Background Technology

[0002] For shale gas with vast resources, the evaluation of EUR (Estimated Ultimate Recovery) is crucial for accurately assessing its development potential and achieving economies of scale. The EUR evaluation process and calculation results form the basis of shale gas reservoir development, influencing well production plans and operational procedures, and are an essential research subject for achieving efficient and scientific gas field development. EUR prediction typically occurs 1-3 months after a gas well is put into production and maintains stable production. It is based on continuous and stable changes in pressure, gas production, and liquid production after well production, combined with reservoir parameters to achieve prediction. Furthermore, multiple dynamic monitoring methods during production are used to iteratively correct the prediction model, improving prediction accuracy. The EUR at this stage is called the producing EUR, and the predicted value is relatively accurate. Furthermore, the accuracy increases with production time and the number of iterations, and the difference in EUR verification values ​​gradually decreases with each iteration. However, EUR production relies on long-term stable production and is a post-production evaluation. When shale gas developers need to assess well capacity in advance and provide decision-making guidance, wells without a long history of stable production cannot be assessed based on EUR production, which restricts the pace of shale gas development.

[0003] Furthermore, natural fractures are well-developed in the shale gas field in southern Sichuan, with a mix of unidirectional and multidirectional fractures. Shale gas wells deployed in a cluster pattern commonly have adjacent or penetrating natural fractures within and between platforms. Because high-intensity fracturing is commonly used in shale gas development in southern Sichuan, inter-well interference, or pressure channeling, easily occurs during fracturing. After pressure channeling occurs, the activating well and the responding well together form a connected well group. At this point, the production dynamics of gas wells within the well group are interconnected and mutually influential, making single-well productivity assessments no longer applicable; productivity prediction needs to be carried out on a well group basis.

[0004] Therefore, there is an urgent need to establish a method for predicting the production capacity of shale gas wells during the completion stage, focusing on well groups with cross-flow characteristics, in order to provide guidance for the advanced production capacity assessment of these well groups. Summary of the Invention

[0005] To address the issue in existing technologies where, after pressure channeling occurs, the activating well and the responding well together form a connected well group, and the production dynamics of gas wells within the group are interconnected and mutually influential, rendering single-well productivity assessments inapplicable, this specification provides a method and apparatus for predicting the productivity of shale gas wells in pressure channeling well groups. This method enables productivity prediction at the well group level, specifically focusing on the productivity prediction during the well completion stage of a shale gas well pressure channeling well group, providing guidance for optimizing gas well development strategies.

[0006] This specification provides a method for predicting the production capacity of shale gas wells in a fracturing well group. The method includes: collecting construction information during the actual fracturing process of each shale gas well in the fracturing well group, and obtaining casing deformation and fracturing-related data in a single shale gas well based on the construction information.

[0007] Based on the aforementioned casing variation, the production capacity of the single-stage shale gas well is predicted to obtain a production capacity prediction result that takes the casing variation into account.

[0008] Based on the aforementioned pressure channeling data, determine whether pressure channeling has occurred in this single-stage shale gas well.

[0009] If no pressure surge occurs, the capacity forecast result considering the conversion will be taken as the final capacity forecast result.

[0010] If pressure channeling occurs, the pressure channeling-related data will be graded and classified for evaluation to obtain the degree of pressure channeling in the single shale gas well.

[0011] Based on the natural fracture distribution information of the single-section shale gas well distribution location, determine the impact of the pressure channeling degree on production capacity;

[0012] The final capacity forecast result is obtained by calculating based on the capacity forecast results considering the variation and the impact of pressure surge.

[0013] Furthermore, the collection of construction information during the actual fracturing operation in each well further includes,

[0014] The construction information includes at least the horizontal length of a single well section, the continuous thickness of the reservoir, the well spacing, the casing deformation, and the pressure channeling.

[0015] Furthermore, based on the aforementioned casing variation, the production capacity of the single-stage shale gas well is predicted, and the production capacity prediction result considering the casing variation is further included.

[0016] The casing deformation situation includes both the case where no casing deformation occurred in the single section of the well and the case where casing deformation occurred in the single section of the well.

[0017] If no casing deformation occurs in the single well section, the formula for calculating the production capacity prediction result during the deployment phase is as follows:

[0018] EUR部署 =0.727*ln(horizontal section length*continuous thickness of Class I reservoir*well spacing)-9.7588,

[0019] If casing deformation occurs in the single-section well, the formula for calculating the production capacity prediction result at the completion stage is as follows:

[0020] EUR 完钻 = (EUR 部署 / L 水平段 )*L 1+2小层 +(EUR 部署 / L 水平段 )*L 3小层 *0.4+(EUR 部署 / L 水平

[0021] 段 )*L 4小层 *0.4+(EUR 部署 / L 水平段 )*L 五峰 *0.2

[0022] Among them, EUR 完钻 This is the production capacity forecast for the drilling completion stage; EUR 部署 This refers to the capacity forecast results during the deployment phase; L 水平段 L is the total horizontal segment length. 1+2小层 The total length encountered in drilling layers 1 and 2; L 3小层 The total length encountered in the three sub-layers; L 4小层 The total length encountered in the 4 sub-layers; L 五峰 This represents the total length of the drilling encountered in the Wufeng Formation.

[0023] Furthermore, determining whether pressure channeling has occurred in this single shale gas well based on the aforementioned pressure channeling-related data further includes:

[0024] The pressure cross-flow related data includes at least the pressure increase of adjacent wells, the well spacing, the pressure rise rate of adjacent wellheads, and the pressure cross-flow distance of the single shale gas well.

[0025] Whether the pressure increase of the adjacent well reaches the threshold is used to determine whether the single-section shale gas well has experienced pressure channeling.

[0026] Furthermore, the pressure channeling-related data is graded and classified for evaluation to obtain the degree of pressure channeling in the single shale gas well. This further includes...

[0027] The response characteristics of the pressure crossflow related data include: pressure crossflow distance, pressure rise rate at adjacent wellheads, and pressure rise rate at adjacent wells;

[0028] Determine the rate of pressure increase at the wellhead of adjacent wells based on the changes in the pattern of pressure increase at the wellhead of adjacent wells;

[0029] The pressure channeling distance and the pressure increase of the adjacent well are evaluated based on a preset threshold.

[0030] The degree of pressure cross-flow in a single well section is determined based on the evaluation results of the pressure cross-flow rate at the wellhead of the adjacent well, the pressure cross-flow distance, and the pressure increase of the adjacent well.

[0031] Furthermore, based on the distribution information of natural fractures at the location of the single-section well, the assessment of the impact of the pressure channeling degree on production capacity further includes:

[0032] The natural fracture distribution information of the location of the single-section well includes: the network fracture development zone and the unidirectional fracture development zone;

[0033] If the natural fracture distribution information is a network fracture development area, then observe the distribution morphology and trend of the pressure fractures in the network fracture development area to determine the impact of the pressure channeling degree on the production capacity.

[0034] If the natural fracture distribution information is a unidirectional fracture development zone, then simulate single-stage fracturing between adjacent wells, and characterize the inter-well fracture connectivity state into three types: strong, medium, and weak, according to a predetermined threshold. Based on the fracture connectivity state, characterize the impact of the fracturing degree on production capacity, and determine the impact coefficient.

[0035] Furthermore, the final capacity forecast result calculated based on the capacity forecast results considering the variation and the impact of pressure surge further includes:

[0036] Based on the capacity forecast results considering the variation and the impact of pressure surge, the calculation formula is as follows:

[0037] EUR 考虑套变+压窜 = (EUR 考虑套变 / L 压裂段 )*L 未压窜段 +(EUR 考虑套变 / L 压裂段 )*L 压窜段 *(1-λ),

[0038] Among them, EUR 考虑套变+压窜 This represents the final production capacity prediction result for the well completion stage of the well control and cross-flow well group; EUR 考虑套变 This is the well completion stage productivity prediction result considering only the effect of casing deformation and not the effect of pressure channeling; L 压裂段 L represents the actual length of the fracturing section during construction. 未压窜段 L is the length of the fracturing section that did not cause an increase in pressure in adjacent wells. 压窜段 The length of the fractured section leading to increased pressure in adjacent wells is given in meters; λ is the coefficient representing the impact of different natural fracture characteristics and varying degrees of pressure channeling on production capacity. This specification provides an embodiment of a device for predicting the production capacity of shale gas wells in a pressure channeling well group. The device includes:

[0039] The information acquisition unit is used to collect construction information during the actual fracturing process of each shale gas well in the fracturing well group, and to obtain casing deformation and fracturing-related data in a single shale gas well based on the construction information.

[0040] The casing variation production capacity prediction unit is used to predict the production capacity of the single-section shale gas well based on the casing variation situation, and obtain the production capacity prediction result considering the casing variation.

[0041] The pressure channeling production capacity prediction unit is used to determine whether pressure channeling has occurred in a single shale gas well based on the pressure channeling-related data.

[0042] The pressure-free unit is used to take the capacity forecast result considering the set-top box as the final capacity forecast result when no pressure crossover occurs.

[0043] The pressure channeling unit is used to classify and evaluate the pressure channeling-related data in the event of pressure channeling to obtain the degree of pressure channeling in a single shale gas well.

[0044] The pressure channeling impact analysis unit is used to determine the pressure channeling impact on production capacity by combining the natural fracture distribution information of the single shale gas well distribution location;

[0045] The final capacity prediction unit is used to calculate the final capacity prediction result based on the capacity prediction result considering the variation and the pressure surge effect.

[0046] This specification 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 operation guidance method.

[0047] This specification also provides a computer-readable storage medium storing a computer program that, when executed by a processor, implements the operation guidance method.

[0048] This specification also provides a computer program product, which includes a computer program that is executed by a processor using the operation guidance method.

[0049] In the embodiments of this specification, by collecting construction information during the actual fracturing process of each shale gas well in the fracturing well group, the casing deformation situation and related data of the single shale gas well are obtained, thereby realizing the comprehensive consideration of the impact of fracturing on each shale gas well in the fracturing well group. First, the production capacity of the single shale gas well is predicted based on the casing deformation situation, and the production capacity prediction result considering the casing deformation is obtained. Then, the production capacity prediction result considering the fracturing is calculated. If no fracturing occurs, the production capacity prediction result considering the casing deformation is the final production capacity prediction result. If fracturing occurs, the related data needs to be graded and classified for evaluation to obtain the degree of fracturing of the single shale gas well. Then, combined with the natural fracture distribution information, the impact of the degree of fracturing on the production capacity is judged. Finally, the final production capacity prediction result is calculated based on the production capacity prediction result considering the casing deformation and the impact of fracturing. This realizes production capacity prediction on a well group basis, and the production capacity prediction method for the completion stage of the shale gas well fracturing well group provides guidance for the optimization of gas well development strategies, greatly saving manpower and time costs. Attached Figure Description

[0050] To more clearly illustrate the technical solutions in the embodiments or prior art of this specification, the drawings used in the description of the embodiments or prior art will be briefly introduced below. Obviously, the drawings described below are only some embodiments of this specification. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0051] Figure 1 The figure shown is a system schematic diagram of a method for predicting the production capacity of shale gas wells in a pressure-driven well group according to an embodiment of this specification;

[0052] Figure 2 The diagram shown is a flowchart of a method for predicting the production capacity of shale gas wells in a pressure-driven well group, according to an embodiment of this specification.

[0053] Figure 3 The diagram shown is a flowchart illustrating how to determine whether pressure channeling occurs in a single-section shale gas well, as described in this specification.

[0054] Figure 4 The diagram shown is a flowchart for determining the degree of pressure channeling in a single shale gas well, as described in an embodiment of this specification.

[0055] Figures 5a-5c The diagram shown is an example of the change in wellhead pressure after an adjacent well is subjected to cross-flow.

[0056] Figures 6a-6c The diagram shown is an example of the pressure increase magnitude corresponding to the three pressure increase classification patterns in the embodiments of this specification.

[0057] Figure 7The diagram shown is a single-segment compression degree evaluation chart according to an embodiment of this specification;

[0058] Figure 8 The diagram shown is an example of how the degree of pressure channeling is determined to affect the production capacity according to an embodiment of this specification.

[0059] Figures 9a-9b The diagram shown is a schematic diagram of the mesh suture development area and the unidirectional suture development area in an embodiment of this specification.

[0060] Figure 10 The diagram shown is a schematic representation of the device for predicting the production capacity of shale gas wells in a well group controlled by pressure channeling, as described in this specification.

[0061] Figure 11 The diagram shown is a structural schematic of a computer device according to an embodiment of this specification.

[0062] Explanation of symbols in the attached drawings:

[0063] 101. Terminal;

[0064] 102. Server;

[0065] 1001. Information Acquisition Unit;

[0066] 1002, Set-up Capacity Forecasting Unit;

[0067] 1003, Pressure Flow Capacity Forecasting Unit;

[0068] 1004, No pressure-crossing unit;

[0069] 1005, Pressure Transmission Unit;

[0070] 1006. Analysis Unit for Pressure Channeling Influence;

[0071] 1007. Final Capacity Forecasting Unit;

[0072] 1102. Computer equipment;

[0073] 1104. Processor;

[0074] 1106. Memory;

[0075] 1108. Drive mechanism;

[0076] 1110. Input / output module;

[0077] 1112. Input devices;

[0078] 1114. Output devices;

[0079] 1116. Presentation device;

[0080] 1118. Graphical User Interface;

[0081] 1120. Network interface;

[0082] 1122. Communication link;

[0083] 1124. Communication bus. Detailed Implementation

[0084] To enable those skilled in the art to better understand the technical solutions in this specification, the technical solutions in the embodiments of this specification will be clearly and completely described below with reference to the accompanying drawings. Obviously, the described embodiments are only some embodiments of this specification, and not all embodiments. Based on the embodiments in this specification, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of this specification.

[0085] It should be noted that the terms "first," "second," etc., in the specification, claims, and accompanying drawings are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover a non-exclusive inclusion; for example, a process, method, apparatus, product, or device that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or devices.

[0086] This specification provides the operational steps of the methods described in the embodiments or flowcharts, but based on conventional or non-inventive labor, more or fewer operational steps may be included. The order of steps listed in the embodiments is merely one possible execution order among many and does not represent the only possible execution order. In actual system or device products, the methods shown in the embodiments or drawings can be executed sequentially or in parallel.

[0087] The acquisition, transmission, storage, use, and processing of data in this application comply with relevant national laws and regulations. It should be noted that certain software, components, models, and other existing industry solutions may be mentioned in the embodiments of this application. These should be considered exemplary, intended only to illustrate the feasibility of implementing the technical solution of this application, and do not imply that the applicant has already used or necessarily used such solutions.

[0088] like Figure 1The diagram illustrates a system schematic of a method for predicting the production capacity of shale gas wells in a well group with cross-linking, according to an embodiment of the present invention. The method includes a terminal 101 and a server 102, which establish a communication connection to enable data exchange. The terminal 101 can acquire complex construction information obtained during the actual fracturing operation of each well and send it to the server 102, including whether casing deformation or cross-linking has occurred at each wellhead and related data. When the server 102 receives the construction information from the actual fracturing operation of each shale gas well in the well group with cross-linking, it addresses the problem that after cross-linking occurs, the activating well and the responding well together form a connected well group with cross-linking, where the mutual influence of gas wells within the group renders single-well production capacity assessments inapplicable. Then, the server 102 uploads the production capacity prediction results of each shale gas well in the well group with cross-linking back to the terminal 101, providing guidance for optimizing gas well development strategies.

[0089] In the embodiments of this specification, the server 102 may be an independent physical server, a server cluster or distributed system composed of multiple physical servers, or a cloud server that provides basic cloud computing services such as cloud services, cloud databases, cloud computing, cloud functions, cloud storage, network services, cloud communication, middleware services, domain name services, security services, content delivery networks (CDN), and big data and artificial intelligence platforms.

[0090] It should be noted that, Figure 1 The example shown is merely one application environment provided by this disclosure. In real applications, other application environments may also be included, but no limitations are imposed in this embodiment of the invention.

[0091] The acquisition, storage, use, and processing of data in this application all comply with the relevant provisions of laws and regulations.

[0092] This paper provides a method for predicting the production capacity of shale gas wells in a pressure-driven well group. The method is based on the correlation between each shale gas well in the pressure-driven well group and pressure-driven related data to obtain a final production capacity prediction result that takes into account the impact of pressure-driven flow. Figure 2 The diagram shows a flowchart of a method for predicting the production capacity of shale gas wells in a pressure-driven well group, as described in this embodiment. The process of calculating the final production capacity prediction result is illustrated in the diagram, but may include more or fewer operational steps based on conventional or non-creative labor. The order of steps listed in the embodiment is merely one possible execution order among many and does not represent the only possible order. In actual system or device products, the method can be executed sequentially or in parallel according to the embodiment or the accompanying drawings. The method specifically includes the following steps:

[0093] Step 201: Collect construction information during the actual fracturing process of each shale gas well in the fracturing well group, and obtain casing deformation and fracturing-related data in a single shale gas well based on the construction information;

[0094] Step 202: Based on the aforementioned casing variation, predict the production capacity of the single-section shale gas well to obtain a production capacity prediction result considering the casing variation;

[0095] Step 203: Determine whether pressure channeling has occurred in the single-stage shale gas well based on the aforementioned pressure channeling data.

[0096] Step 204: If no pressure surge occurs, the capacity forecast result considering the conversion is taken as the final capacity forecast result;

[0097] Step 205: If pressure channeling occurs, the pressure channeling-related data are graded and classified for evaluation to obtain the degree of pressure channeling in the single shale gas well.

[0098] Step 206: Based on the natural fracture distribution information of the single-segment shale gas well distribution location, determine the impact of the pressure channeling degree on the production capacity;

[0099] Step 207: Calculate the final capacity prediction result based on the capacity prediction result considering the variation and the pressure surge effect.

[0100] In the embodiments of this specification, by collecting construction information during the actual fracturing process of each shale gas well in the fracturing well group, the casing deformation situation and related data of the single shale gas well are obtained, thereby realizing the comprehensive consideration of the impact of fracturing on each shale gas well in the fracturing well group. First, the production capacity of the single shale gas well is predicted based on the casing deformation situation, and the production capacity prediction result considering the casing deformation is obtained. Then, the production capacity prediction result considering the fracturing is calculated. If no fracturing occurs, the production capacity prediction result considering the casing deformation is the final production capacity prediction result. If fracturing occurs, the related data needs to be graded and classified for evaluation to obtain the degree of fracturing of the single shale gas well. Then, combined with the natural fracture distribution information, the impact of the degree of fracturing on the production capacity is judged. Finally, the final production capacity prediction result is calculated based on the production capacity prediction result considering the casing deformation and the impact of fracturing. This realizes production capacity prediction on a well group basis, and the production capacity prediction method for the completion stage of the shale gas well fracturing well group provides guidance for the optimization of gas well development strategies, greatly saving manpower and time costs.

[0101] In the embodiments of this specification, in order to conduct advanced production capacity assessment of fracturing well groups, it is necessary to collect construction information during the actual fracturing operation of each well, which further includes...

[0102] The construction information includes at least the horizontal length of a single well section, the continuous thickness of the reservoir, the well spacing, the casing deformation, and the pressure channeling.

[0103] Information such as the horizontal length of a single well section, the continuous thickness of the reservoir, and the well spacing are used to calculate the production capacity prediction results during the deployment phase, assuming no casing pressure shifting or channeling occurs.

[0104] In the embodiments of this specification, in order to obtain a production capacity prediction result considering casing variations, the production capacity of the single-stage shale gas well is predicted based on the casing variations. Obtaining a production capacity prediction result considering casing variations further includes...

[0105] The casing deformation situation includes both the case where no casing deformation occurred in the single section of the well and the case where casing deformation occurred in the single section of the well.

[0106] If no casing deformation occurs in the single section well, the formula for calculating the production capacity prediction result is as follows:

[0107] EUR 部署 =0.727*ln(horizontal section length*continuous thickness of Class I reservoir*well spacing)-9.7588,

[0108] If the single-section well experiences casing deformation, the formula for calculating the production capacity prediction result is as follows:

[0109] EUR 完钻 = (EUR 部署 / L 水平段 )*L 1+2小层 +(EUR 部署 / L 水平段 )*L 3小层 *0.4+(EUR 部署 / L 水平

[0110] 段 )*L 4小层 *0.4+(EUR 部署 / L 水平段 )*L 五峰 *0.2

[0111] Among them, EUR 完钻 This is the production capacity forecast for the drilling completion stage; EUR 部署 This refers to the capacity forecast results during the deployment phase; L 水平段 L is the total horizontal segment length. 1+2小层 The total length encountered in drilling layers 1 and 2; L 3小层 The total length encountered in the three sub-layers; L 4小层 The total length encountered in the 4 sub-layers; L 五峰 This represents the total length of the drilling encountered in the Wufeng Formation.

[0112] In the embodiments of this specification, since shale gas wells need to go through multiple development stages such as deployment, drilling, fracturing, flowback, and production, once fracturing is completed, the reservoir quality, drilling quality, and fracturing effect are all finalized, and the conditions for preliminary EUR prediction are basically met. Therefore, in order to balance the accuracy and advance prediction of EUR prediction, the EUR prediction at the completion stage is chosen in the final stage before well opening, i.e., after fracturing. If no casing deformation occurs in a single section of the well, the calculation formula is the same as the production prediction formula for the deployment stage; if casing deformation occurs in a single section of the well, the calculation formula for the production prediction result is the same as the production prediction result formula for the completion stage.

[0113] In the embodiments of this specification, in order to determine whether pressure channeling has occurred in a shale gas well, such as Figure 3 As shown, determining whether pressure channeling has occurred in a single shale gas well based on the aforementioned pressure channeling-related data further includes:

[0114] Step 301: The pressure cross-flow related data includes at least the pressure increase of adjacent wells, the well spacing, the pressure rise rate of adjacent wellheads, and the pressure cross-flow distance of the single shale gas well.

[0115] Step 302: Determine whether the single-section shale gas well has experienced pressure channeling based on whether the pressure increase of the adjacent well reaches the threshold.

[0116] Specifically, pressure channeling typically manifests as an abnormal increase in wellhead pressure detected in adjacent wells during fracturing of one well. This may indicate underground fracture connectivity issues such as stress disturbance, fracturing fluid channeling, or proppant channeling. The response characteristics of pressure channeling mainly include three factors: channeling distance, the rate of pressure increase at the wellhead of the adjacent well, and the pressure increase in the adjacent well. The magnitude of the pressure increase, the speed of the pressure increase, and the distance of the channeling are key factors in classifying and evaluating the degree of pressure channeling.

[0117] In the embodiments of this specification, when specifically determining the degree of pressure channeling, it is also necessary to classify and evaluate the pressure channeling-related data. The response characteristics of the pressure channeling-related data include: pressure channeling distance, the rate of pressure increase at the wellhead of adjacent wells, and the pressure increase rate of adjacent wells. Specifically, for example... Figure 4 As shown, obtaining the pressure channeling degree of this single shale gas well further includes,

[0118] Step 401: Determine the rate of pressure increase at the wellhead of the adjacent well based on the changes in the pressure increase pattern of the adjacent well.

[0119] Step 402: Evaluate the pressure channeling distance and the pressure increase of the adjacent well according to a preset threshold;

[0120] Step 403: Determine the degree of pressure cross-flow in the single well section based on the evaluation results of the pressure cross-flow rate at the wellhead of the adjacent well, the pressure cross-flow distance, and the pressure increase of the adjacent well.

[0121] Specifically, such as Figures 5a-5c As shown, based on the changes in the wellhead pressure rise pattern after the adjacent well was subjected to cross-flow, the main characteristics can be observed as follows: Figure 5a Step-like rise Figure 5b rapid rise Figure 5c The pressure rise is characterized by three slow increases. Statistical analysis shows that the corresponding pressure rise rates for the three categories are 0.31, 0.14, and 0.06 MPa / min, respectively. Simultaneously, the magnitude of the pressure rise also needs to be considered, such as... Figures 6a-6c As shown, the pressure increase ranges for the three pressure increase categories are 5.54–14.52 MPa, 2.74–7.37 MPa, and 0.96–2.59 MPa, respectively, with average fracturing increases of 10.38 MPa, 4.92 MPa, and 1.72 MPa, respectively. Monitoring of multiple shale gas wells with liquid phase tracers revealed that in fracturing sections where liquid phase tracers were detected and pressure increases were observed, the pressure increase was generally greater than 5 MPa. Therefore, when the pressure increase exceeds 5 MPa, "fracturing fluid channeling" is considered to exist, indicating a high degree of channeling. Based on current research, rapid or stepped increases are mainly caused by fracturing fluid channeling, characterized by a fast rate and large magnitude of increase; slow increases are mainly caused by inter-well stress interference, characterized by a slow rate and small magnitude of increase. Therefore, when rapid or stepped increases occur, it can be determined that channeling has occurred in the single shale gas well segment.

[0122] For example, taking actual fracturing fluid crosstalk as an example, during the 18th stage fracturing of well L76-4 in the southern Sichuan region, wells H66-1 / 2 / 3 experienced crosstalk, with a maximum crosstalk distance of 900m and a maximum pressure increase in adjacent wells of 12.1MPa; during the 3rd stage fracturing of well L6-4, well L7-4 experienced crosstalk and overflow, with a maximum crosstalk distance of 1200m. That is, when the crosstalk distance is greater than twice the well spacing, "fracturing fluid crosstalk" exists between adjacent wells, with a high degree of crosstalk and significant impact. Figure 7 As shown, based on comprehensive big data statistical analysis, dynamic monitoring results, and pressure channeling response patterns, and using inter-well stress interference and fracturing fluid channeling as evaluation criteria, a single-stage pressure channeling evaluation chart for "fracturing-fracturing" type pressure channeling was established, classifying it into strong, medium, and weak pressure channeling types.

[0123] In the embodiments of this specification, in order to further determine the impact of the pressure surge degree on production capacity, such as... Figure 8 As shown, it is also necessary to combine the natural fracture distribution information of the distribution location of the single well section, which includes: the network fracture development zone and the unidirectional fracture development zone.

[0124] Step 801: Determine the impact of the pressure crosstalk degree on the pressure crosstalk generated by the production capacity;

[0125] Step 802: If the natural crack distribution information is a network crack development area, then observe the distribution morphology and trend of the pressure cracks in the network crack development area to determine the impact of the pressure channeling degree on the production capacity.

[0126] Step 803: If the natural fracture distribution information is a unidirectional fracture development zone, then simulate single-stage fracturing between adjacent wells, and characterize the inter-well fracture connectivity state into three types: strong, medium, and weak, according to a predetermined threshold. Based on the fracture connectivity state, characterize the impact of the fracturing degree on the production capacity, and determine the impact coefficient.

[0127] Specifically, highly developed natural fractures, and the different distribution characteristics of these fractures, have varying degrees of impact on gas well productivity. Therefore, based on the single-stage pressure channeling evaluation chart, such as... Figures 9a-9b As shown, numerical simulation technology is applied to predict the production capacity of wells with cross-linking during the completion stage, specifically targeting areas with reticular fracture development and unidirectional fracture development, and a quantitative evaluation method for the impact of cross-linking on production capacity is established. Among these methods, Figure 9a The middle section is a network fracture development zone. Using well trajectory or network natural fracture distribution models, combined with constraints from actual single-stage fracturing pumping procedures, single-stage fracturing simulations were completed for adjacent sections of two wells. By characterizing strong, medium, and weak inter-well fracture connectivity states, three degrees of fracturing were represented. The fracture distribution morphology and trend were observed, revealing that overall fracturing modification is relatively uniform in the network fracture development zone. The network distribution of natural fractures helps form a more complex fracture network. The differences in modification effects brought about by different degrees of fracturing are small, ultimately tending towards uniform modification. Figure 9b The middle section is a unidirectional fracture development zone. By characterizing the three inter-well fracture connectivity states of strong, medium and weak, the three degrees of pressure channeling are represented. The distribution morphology and trend of the pressure fractures are observed. It can be clearly found that the effect of pressure channeling in the unidirectional fracture development zone is greatly affected by the degree of pressure channeling. The unidirectional strip distribution of natural fractures easily leads to the fracturing fluid being captured by the natural fractures, causing the pressure fractures to spread along the natural fractures. This results in a large pressure increase in adjacent wells, uneven pressure channeling, and a small channeling range.

[0128] In the embodiments of this specification, the final capacity prediction result calculated based on the capacity prediction result considering the variation and the impact of pressure surge further includes:

[0129] Based on the capacity forecast results considering the variation and the impact of pressure surge, the calculation formula is as follows:

[0130] EUR 考虑套变+压窜 = (EUR 考虑套变 / L 压裂段 )*L 未压窜段 +(EUR 考虑套变 / L 压裂段 )*L 压窜段 *(1-λ),

[0131] Among them, EUR 考虑套变+压窜 This represents the final production capacity prediction result for the well completion stage of the well control and cross-flow well group; EUR 考虑套变 This is the well completion stage productivity prediction result considering only the effect of casing deformation and not the effect of pressure channeling; L 压裂段 L represents the actual length of the fracturing section during construction. 未压窜段 L is the length of the fracturing section that did not cause an increase in pressure in adjacent wells. 压窜段 The length of the fractured section that causes pressure increase in adjacent wells is given in meters; λ is the coefficient of influence of different natural fracture characteristics and different degrees of pressure channeling on production capacity.

[0132] Specifically, insufficient wellbore stimulation due to cross-contamination is the main factor contributing to EUR loss. EUR loss is quantitatively evaluated based on the degree of cross-contamination. A EUR prediction model for the completion stage is established, taking into account the distribution characteristics of natural fractures and the degree of cross-contamination. 考虑套变+压窜 By EUR 未压窜段 EUR 压窜段 composition:

[0133] EUR 考虑套变+压窜 = (EUR 考虑套变 / L 压裂段 )*L 未压窜段 +(EUR 考虑套变 / L 压裂段 )*L 压窜段 *(1-λ),

[0134] The value of λ is based on the quantitative loss degree obtained from the simulation of the impact of different natural crack characteristics and different degrees of pressure channeling on production capacity in the previous text.

[0135] For example, examples are given for wells with no casing deformation and pressure channeling, wells with casing deformation and pressure channeling, wells with no casing deformation but pressure channeling, and wells with casing deformation but no pressure channeling. EUR is then performed sequentially according to the above process. 部署 EUR 完钻 EUR 考虑套变 EUR 考虑套变+压窜 Forecast, of which EUR 部署 EUR 完钻 All parameters are the same:

[0136] The horizontal section of this well is 1500 meters long, the Class I reservoir has a continuous thickness of 10 meters, and the well spacing is 350 meters. Substituting these values ​​into the formula, the calculation is: EUR 部署 =0.727*ln(1500*10*350)-9.7588≈1.49 (billion cubic meters)

[0137] The drilling length of sub-layers 1+2 in this well is 1000 meters, sub-layer 3 is 300 meters, sub-layer 4 is 150 meters, and the length of the Wufeng group is 50 meters. Substituting these values ​​into the formula, the calculation is as follows:

[0138] EUR 完钻 = (1.49 / 1500)*1000 + (1.49 / 1500)*300*0.4 + (1.49 / 1500)*150*0.4 +

[0139] (1.49 / 1500)*50*0.2≈1.18 (100 million cubic meters)

[0140] If no casing pressure shift or well channeling occurred, the actual fracturing length of this well is 1400 meters. Substituting this into the formula, the calculation is as follows:

[0141] EUR 完井 =1.18 / 1500*1400≈1.10 (100 million cubic meters)

[0142] If a casing deformation occurs and the well is subjected to hydraulic fracturing, the actual fracturing length of this well is 1400 meters, of which 1300 meters are normal fracturing operations and 100 meters are reduced in scale due to the casing deformation.

[0143] Regarding pressure channeling, this well is located in a region with well network fractures. During fracturing, a 1000-meter-long fracturing section did not experience pressure channeling, while a 400-meter-long fracturing section caused pressure increases in adjacent wells, with increases generally exceeding 5 MPa. Multiple adjacent wells experienced pressure channeling, with the furthest channeling distance exceeding 600 meters. The pressure increases in adjacent wells were mainly step-like, indicating a strong degree of pressure channeling.

[0144] Then, substituting into the formula, the calculation is as follows:

[0145] EUR 考虑套变 = 1.18 / 1500*1300 + 1.18 / 1500*100*78% ≈ 1.08 (100 million cubic meters)

[0146] EUR 完井 = 1.08 / 1400*1000 + 1.08 / 1400*400*(1-0.1) ≈ 1.05 (100 million cubic meters)

[0147] If casing deformation did not occur but pressure channeling did, the actual fracturing length of this well was 1400 meters, and no casing deformation occurred. Regarding pressure channeling, this well is located in a region with well-developed network fractures. During fracturing, a 1000-meter section did not experience pressure channeling, while a 400-meter section caused pressure increases in adjacent wells, with increases generally exceeding 5 MPa. Multiple adjacent wells experienced pressure channeling, with the furthest channeling distance exceeding 600 meters. The pressure increases in adjacent wells were mainly step-like, indicating a high degree of pressure channeling.

[0148] Then, substituting into the formula, the calculation is as follows:

[0149] EUR 考虑套变 =1.18 / 1500*1400≈1.10 (100 million cubic meters)

[0150] EUR 完井 =1.10 / 1400*1000+1.10 / 1400*400*(1-0.1)≈1.07 (100 million cubic meters)

[0151] If casing deformation occurred but no fracturing occurred, then regarding casing deformation, the actual fracturing length of this well was 1400 meters, of which 1300 meters were normal fracturing operations, and 100 meters were reduced in scale due to casing deformation, and no fracturing occurred.

[0152] Then, substituting into the formula, the calculation is as follows:

[0153] EUR 完井 =EUR 考虑套变 =1.18 / 1500*1300 + 1.18 / 1500*100*78% ≈ 1.08 (100 million cubic meters)

[0154] This invention analyzes and evaluates the characteristics of cross-flow response through its embodiments, identifying four key evaluation indicators for cross-flow severity: pressure increase in adjacent wells, pressure increase rate, cross-flow distance, and the proportion of cross-flow segments. A single-segment cross-flow severity evaluation chart is established using big data analysis, enabling graded and categorized evaluation of cross-flow severity. Combined with numerical simulation, the impact of different cross-flow degrees on production is quantified. Finally, based on previous research results and the single-well completion stage EUR prediction model, an optimized completion stage EUR prediction model considering cross-flow losses is developed. The expected effect of this invention is to proactively evaluate the production capacity after cross-flow well modification, enabling timely guidance for backflow and production system adjustments, and early optimization of deployment or construction measures to achieve optimal production results and support the large-scale and efficient development of shale gas.

[0155] like Figure 10 The image shown is an embodiment of an apparatus for predicting the production capacity of shale gas wells in a pressure-driven well group, as described in this specification. The apparatus specifically includes:

[0156] The information acquisition unit 1001 is used to collect construction information during the actual fracturing process of each shale gas well in the fracturing well group, and to obtain casing deformation and fracturing-related data in a single shale gas well based on the construction information.

[0157] The casing variation production capacity prediction unit 1002 is used to predict the production capacity of the single-section shale gas well based on the casing variation situation, and obtain the production capacity prediction result considering the casing variation.

[0158] The pressure channeling production capacity prediction unit 1003 is used to determine whether pressure channeling has occurred in a single shale gas well based on the pressure channeling-related data.

[0159] The pressure-free unit 1004 is used to take the capacity prediction result considering the set-top box as the final capacity prediction result when no pressure crossover occurs.

[0160] The pressure channeling unit 1005 is used to classify and evaluate the pressure channeling-related data in the event of pressure channeling to obtain the degree of pressure channeling in a single shale gas well.

[0161] The pressure channeling impact analysis unit 1006 is used to determine the pressure channeling impact on production capacity by combining the natural fracture distribution information of the single-segment shale gas well distribution location.

[0162] The final capacity prediction unit 1007 is used to calculate the final capacity prediction result based on the capacity prediction result considering the variation and the pressure crossover effect.

[0163] like Figure 11 As shown, a computer device 1102 provided in an embodiment of this specification may include one or more processors 1104, such as one or more central processing units (CPUs), each of which may implement one or more hardware threads. The computer device 1102 may also include any memory 1106 for storing information of any kind, such as code, settings, data, etc. Without limitation, for example, the memory 1106 may include any type of RAM, any type of ROM, flash memory, hard disk, optical disk, etc. More generally, any memory may use any technology to store information. Further, any memory may provide volatile or non-volatile retention of information. Further, any memory may represent a fixed or removable component of the computer device 1102. In one case, when the processor 1104 executes associated instructions stored in any memory or combination of memories, the computer device 1102 may perform any operation of the associated instructions. The computer device 1102 also includes one or more drive mechanisms 1108 for interacting with any memory, such as hard disk drive mechanisms, optical disk drive mechanisms, etc.

[0164] Computer device 1102 may also include an input / output module 1110 (I / O) for receiving various inputs (via input device 1112) and providing various outputs (via output device 1114). A specific output mechanism may include a presentation device 1116 and an associated graphical user interface (GUI) 1118. In other embodiments, the input / output module 1110 (I / O), input device 1112, and output device 1114 may be omitted, and the device may function solely as a computer device within a network. Computer device 1102 may also include one or more network interfaces 1120 for exchanging data with other devices via one or more communication links 1122. One or more communication buses 1124 couple the components described above together.

[0165] Communication link 1122 can be implemented in any way, such as via a local area network, a wide area network (e.g., the Internet), a point-to-point connection, or any combination thereof. Communication link 1122 may include any combination of hardwired links, wireless links, routers, gateway functions, name servers, etc., governed by any protocol or combination of protocols.

[0166] Corresponding to Figures 1 to 8 In addition to the methods described above, embodiments of this specification also provide a computer-readable storage medium storing a computer program that, when executed by a processor, performs the steps of the methods described above.

[0167] This specification also provides computer-readable instructions, wherein when a processor executes the instructions, the program therein causes the processor to perform the following... Figures 1 to 8 The method shown.

[0168] This specification also provides a computer program product, which includes a computer program that is executed by a processor, such as... Figures 1 to 8 The method shown.

[0169] It should be understood that in the various embodiments of this specification, the sequence number of each process does not imply the order of execution. The execution order of each process should be determined by its function and internal logic, and should not constitute any limitation on the implementation process of the embodiments of this specification.

[0170] It should also be understood that, in the embodiments of this specification, the term "and / or" is merely a description of the relationship between related objects, indicating that three relationships can exist. For example, A and / or B can represent: A existing alone, A and B existing simultaneously, and B existing alone. Additionally, the character " / " in this specification generally indicates that the preceding and following related objects have an "or" relationship.

[0171] Those skilled in the art will recognize that the units and algorithm steps of the various examples described in conjunction with the embodiments disclosed in this specification can be implemented in electronic hardware, computer software, or a combination of both. To clearly illustrate the interchangeability of hardware and software, the components and steps of each example have been generally described in terms of functionality in the foregoing description. Whether these functions are implemented in hardware or software depends on the specific application and design constraints of the technical solution. Those skilled in the art can use different methods to implement the described functions for each specific application, but such implementation should not be considered beyond the scope of this specification.

[0172] Those skilled in the art will clearly understand that, for the sake of convenience and brevity, the specific working processes of the systems, devices, and units described above can be referred to the corresponding processes in the foregoing method embodiments, and will not be repeated here.

[0173] In the several embodiments provided in this specification, it should be understood that the disclosed systems, apparatuses, and methods can be implemented in other ways. For example, the apparatus embodiments described above are merely illustrative; for instance, the division of units is only a logical functional division, and in actual implementation, there may be other division methods. For example, multiple units or components may be combined or integrated into another system, or some features may be ignored or not executed. Furthermore, the couplings or direct couplings or communication connections shown or discussed may be indirect couplings or communication connections through some interfaces, devices, or units, or they may be electrical, mechanical, or other forms of connection.

[0174] The units described as separate components may or may not be physically separate. The components shown as units may or may not be physical units; that is, they may be located in one place or distributed across multiple network units. Some or all of the units can be selected to achieve the purpose of the embodiments described in this specification, depending on actual needs.

[0175] Furthermore, the functional units in the various embodiments of this specification can be integrated into one processing unit, or each unit can exist physically separately, or two or more units can be integrated into one unit. The integrated unit can be implemented in hardware or as a software functional unit.

[0176] If the integrated unit is implemented as a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of this specification, in essence, or the part that contributes to the prior art, or all or part of the technical solution, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute all or part of the steps of the methods described in the various embodiments of this specification. The aforementioned storage medium includes various media capable of storing program code, such as USB flash drives, portable hard drives, read-only memory (ROM), random access memory (RAM), magnetic disks, or optical disks.

[0177] This specification uses specific embodiments to illustrate the principles and implementation methods of this specification. The descriptions of the above embodiments are only for the purpose of helping to understand the methods and core ideas of this specification. At the same time, for those skilled in the art, there will be changes in the specific implementation methods and application scope based on the ideas of this specification. Therefore, the content of this specification should not be construed as a limitation of this specification.

Claims

1. A method for predicting the production capacity of shale gas wells in a well group with pressure channeling, characterized in that, The method includes: Collect construction information on the actual fracturing process of each shale gas well in the fracturing well group, and obtain casing deformation and related data on fracturing in a single shale gas well based on the construction information; Based on the aforementioned casing variation, the production capacity of the single-stage shale gas well is predicted to obtain a production capacity prediction result that takes the casing variation into account. Based on the aforementioned pressure channeling data, determine whether pressure channeling has occurred in this single-stage shale gas well. If no pressure surge occurs, the capacity forecast result considering the conversion will be taken as the final capacity forecast result. If pressure channeling occurs, the pressure channeling-related data will be graded and classified for evaluation to obtain the degree of pressure channeling in the single shale gas well. Based on the natural fracture distribution information of the single-section shale gas well distribution location, determine the impact of the pressure channeling degree on production capacity; The final capacity forecast result is obtained by calculating based on the capacity forecast results considering the variation and the impact of pressure surge.

2. The method for predicting the production capacity of shale gas wells in a well group under pressure and channeling according to claim 1, characterized in that, The collection of actual fracturing process information for each well further includes, The construction information includes at least the horizontal length of a single well section, the continuous thickness of the reservoir, the well spacing, the casing deformation, and the pressure channeling.

3. The method for predicting the production capacity of shale gas wells in a well group under pressure and channeling according to claim 2, characterized in that, Based on the aforementioned casing variation, the production capacity of the single-stage shale gas well is predicted, and the production capacity prediction result considering the casing variation further includes... The casing deformation situation includes both the case where no casing deformation occurred in the single section of the well and the case where casing deformation occurred in the single section of the well. If no casing deformation occurs in the single section well, the formula for calculating the production capacity prediction result is as follows: EUR 部署 =0.727*ln(horizontal section length*continuous thickness of Class I reservoir*well spacing)-9.7588, If the single-section well experiences casing deformation, the formula for calculating the production capacity prediction result is as follows: EUR 完钻 < (EUR 部署 / L 水平段 )*L 1+2小层 +(EUR 部署 / L 水平段 )*L 3小层 *0.4+(EUR 部署 / L 水平段 )*L 4小层 *0.4+(EUR 部署 / L 水平段 )*L 五峰 *0.2 Among them, EUR 完钻 This is the production capacity forecast for the drilling completion stage; EUR 部署 This refers to the capacity forecast results during the deployment phase; L 水平段 L is the total horizontal segment length. 1+2小层 The total length encountered in drilling layers 1 and 2; L 3小层 The total length encountered in the three sub-layers; L 4小层 The total length encountered in the 4 sub-layers; L 五峰 This represents the total length of the drilling encountered in the Wufeng Formation.

4. The method for predicting the production capacity of shale gas wells in a well group under pressure and channeling as described in claim 3, characterized in that, Determining whether pressure channeling has occurred in a single shale gas well based on the aforementioned pressure channeling-related data further includes... The pressure cross-flow related data includes at least the pressure increase of adjacent wells, the well spacing, the pressure rise rate of adjacent wellheads, and the pressure cross-flow distance of the single shale gas well. Whether the pressure increase of the adjacent well reaches the threshold is used to determine whether the single-section shale gas well has experienced pressure channeling.

5. The method for predicting the production capacity of shale gas wells in a well group with pressure channeling according to claim 4, characterized in that, The pressure channeling-related data are graded and classified for evaluation. Further methods to determine the degree of pressure channeling in a single shale gas well include: The response characteristics of the pressure crossflow related data include: pressure crossflow distance, pressure rise rate at adjacent wellheads, and pressure rise rate at adjacent wells; Determine the rate of pressure increase at the wellhead of adjacent wells based on the changes in the pattern of pressure increase at the wellhead of adjacent wells; The pressure channeling distance and the pressure increase of the adjacent well are evaluated based on a preset threshold. The degree of pressure cross-flow in a single well section is determined based on the evaluation results of the pressure cross-flow rate at the wellhead of the adjacent well, the pressure cross-flow distance, and the pressure increase of the adjacent well.

6. The method for predicting the production capacity of shale gas wells in a well group under pressure and channeling as described in claim 5, characterized in that, Based on the distribution information of natural fractures at the locations of the individual well sections, the assessment of the impact of the pressure channeling degree on production capacity further includes: The natural fracture distribution information of the location of the single-section well includes: the network fracture development zone and the unidirectional fracture development zone; If the natural fracture distribution information is a network fracture development area, then observe the distribution morphology and trend of the pressure fractures in the network fracture development area to determine the impact of the pressure channeling degree on the production capacity. If the natural fracture distribution information is a unidirectional fracture development zone, then simulate single-stage fracturing between adjacent wells, and characterize the inter-well fracture connectivity state into three types: strong, medium, and weak, according to a predetermined threshold. Based on the fracture connectivity state, characterize the impact of the fracturing degree on production capacity, and determine the impact coefficient.

7. The method for predicting the production capacity of shale gas wells in a well group with pressure channeling according to claim 6, characterized in that, The final capacity forecast result, calculated based on the capacity forecast results considering the variation and the impact of pressure surge, further includes... Based on the capacity forecast results considering the variation and the impact of pressure surge, the calculation formula is as follows: EUR 考虑套变+压窜 < (EUR 考虑套变 / L 压裂段 )*L 未压窜段 +(EUR 考虑套变 / L 压裂段 )*L 压窜段 *(1-λ), Among them, EUR 考虑套变+压窜 This represents the final production capacity prediction result for the well completion stage of the well control and cross-flow well group; EUR 考虑套变 This is the well completion stage productivity prediction result considering only the effect of casing deformation and not the effect of pressure channeling; L 压裂段 L represents the actual length of the fracturing section during construction. 未压窜段 L is the length of the fracturing section that did not cause an increase in pressure in adjacent wells. 压窜段 The length of the fractured section that causes pressure increase in adjacent wells is given in meters; λ is the coefficient of influence of different natural fracture characteristics and different degrees of pressure channeling on production capacity.

8. A device for predicting the production capacity of shale gas wells in a well group with pressure channeling, characterized in that, The device includes: The information acquisition unit is used to collect construction information during the actual fracturing process of each shale gas well in the fracturing well group, and to obtain casing deformation and fracturing-related data in a single shale gas well based on the construction information. The casing variation production capacity prediction unit is used to predict the production capacity of the single-section shale gas well based on the casing variation situation, and obtain the production capacity prediction result considering the casing variation. The pressure channeling production capacity prediction unit is used to determine whether pressure channeling has occurred in a single shale gas well based on the pressure channeling-related data. The pressure-free unit is used to take the capacity forecast result considering the set-top box as the final capacity forecast result when no pressure crossover occurs. The pressure channeling unit is used to classify and evaluate the pressure channeling-related data in the event of pressure channeling to obtain the degree of pressure channeling in a single shale gas well. The pressure channeling impact analysis unit is used to determine the pressure channeling impact on production capacity by combining the natural fracture distribution information of the single shale gas well distribution location; The final capacity prediction unit is used to calculate the final capacity prediction result based on the capacity prediction result considering the variation and the pressure surge effect.

9. A computer device, comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that, When the processor executes the computer program, it implements the method according to any one of claims 1 to 7.

10. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores a computer program that, when executed by a processor, implements the method according to any one of claims 1 to 7.

11. A computer program product, characterized in that, The computer program product includes a computer program that, when executed by a processor, implements the method of any one of claims 1 to 7.

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