104 results about "Reservoir engineering" patented technology

The invention belongs to the technical field of oil and gas reservoir energy development, and discloses a three-dimensional injection and production well pattern construction method based on a multi-objective algorithm. The problem that the delimited potential area is difficult to effectively use due to the fact that existing potential evaluation is only based on a single index is effectively solved. Comprising the steps that a fault inner core, a fault outer core, a fracture development dense zone and a secondary fracture zone are proposed; carrying out inter-well connectivity analysis on the oil reservoir units by utilizing an oil reservoir engineering method and a numerical simulation streamline method; based on the embedded discrete fracture model, analyzing a remaining oil distribution mode under the control of the nuclear band structure; a multi-parameter comprehensive evaluation system is constructed by combining the remaining oil utilization potential, the displacement power, the flow capacity, the connectivity relation and the reserve abundance; a three-dimensional injection-production well pattern construction technology is formed for an oil reservoir with or without bottom water; based on a multi-objective optimization algorithm, three-dimensional collaborative optimization of the recovery ratio, the well control reserves and the net present value is taken as a core, and a high-efficiency well location deployment technology for different fault zones is constructed.

The invention relates to the technical field of oil and gas equipment operation control, in particular to an oil and gas equipment operation parameter self-adaptive fine tuning method and system, and the method comprises the steps: constructing an operation parameter optimization library driven by reinforcement learning, defining an action space containing equipment types, working condition modes and key parameter combinations, predicting accuracy, response efficiency and safety compliance are optimized in combination with a multi-target reward function, an optimized instruction set is generated, safety perception mixing precision fine adjustment is carried out in parallel, calculation precision is configured in a layered mode, errors are monitored in real time, a high-precision mode is switched if the precision exceeds the limit, and a reservoir engineering equation mechanism constraint matrix is embedded to guide parameter updating. A generative adversarial network is utilized to synthesize fault data, a Darcy seepage causal engine is integrated to correct a loss function, the system comprises an action space construction unit, a precision dynamic scheduling unit, a mechanism constraint embedding unit and a data causal cooperation unit, and the method and the system realize data-mechanism fusion, balance precision and real-time performance, and improve equipment operation safety and adaptability.

The invention discloses an injection-production well connectivity modeling and yield prediction method and device, and relates to the technical field of oil reservoir engineering. Comprising the following steps: on the basis of preprocessed time sequence injection-production data, constructing a spatial topological graph structure according to screening conditions; constructing a yield prediction model based on the LSTM-GAT network, taking the spatial topological graph structure as the input of a graph attention mechanism, extracting the time dependence characteristics of the gas injection well and the production well by using the long short-term memory network, and extracting the spatial dependence relationship of the gas injection well and the production well by using the graph attention mechanism so as to output the predicted yield of the production well at the future moment; constructing a fitness function, and introducing a whale optimization algorithm to perform global optimization on the injection-production parameters to obtain an optimal injection-production parameter combination; and outputting the optimal injection-production parameter combination. The problems that when an existing method is used for determining the inter-well communication relation, a large amount of geological data and experiment cost are needed, the analysis process is complex, consumed time is long, and accurate optimization of injection-production parameters is difficult to achieve are solved.

The invention provides a deep energy reservoir multi-scale heat-fluid-solid coupling simulation method and system, and belongs to the field of deep energy reservoir numerical simulation. Acquiring spatial distribution characteristics and physical property parameters of different lithologic reservoir media under a micro-scale, and constructing a digital structure model of the reservoir media; a micro-observation action mechanism and a flow mechanism are embedded in the model to obtain a micro-observation numerical model; establishing a mapping relation by solving model structure parameters and physical property parameters of the microscopic numerical model under different thermal-fluid-solid coupling conditions; and on the basis of the mapping relationship, in combination with the macrogeological and engineering data of the target reservoir, establishing a macroscale heat-fluid-solid multi-field coupling control equation and solving, and outputting the multi-physics field response of the target reservoir under the given working condition. According to the method, fine simulation of physical property parameter dynamic transmission and a multi-field coupling evolution process from a micro view to a macro view is realized, and the accuracy and reliability of deep complex reservoir engineering behavior prediction are remarkably improved.

The invention discloses a global fracture conductivity ultra-long-term prediction method and system, belongs to the technical field of crossing of oil and gas reservoir engineering and artificial intelligence, and is used for solving the technical problem that the calculation cost is high when an existing physical model is used for predicting fracture ultra-long-term conductivity. The method comprises the following steps: generating a global fracture conductivity evolution data set covering multiple working conditions through a numerical simulation system; constructing a multi-channel input tensor containing dynamic fracture conductivity and static proppant concentration distribution; using the data set to train a plurality of Fourier neural operator models for different prediction time scales; and based on a hierarchical time sequence aggregation strategy, iteratively calling trained models of different time scales, and realizing rapid prediction of fracture conductivity in a few years to tens of years in the future. According to the method, on the premise of ensuring the prediction precision, the calculation time consumption of ultra-long-term prediction can be remarkably reduced, and decision support is provided for crack design and production strategy optimization.

The invention is applicable to the field of oil and gas geophysical exploration, and provides a shale solid skeleton and organic matter elastic parameter synchronous prediction method, which comprises the following steps of: constructing a rock physical model for representing a shale reservoir solid skeleton elastic modulus and an organic matter elastic modulus; developing an in-well inversion method based on the rock physical model; combining a rock physical model and a scattering function theory, and establishing a reflection coefficient formula represented by shale solid skeleton elasticity modulus, organic matter elasticity modulus and density parameter linearization; a reflection coefficient formula and a Bayesian linear inversion theory are combined to develop an earthquake rock physical inversion method; applying synthetic seismic data, and testing and verifying the effectiveness of the seismic rock physical inversion method constructed in the step E; and then the method is applied to actual seismic data to predict the elasticity modulus of a shale gas reservoir solid skeleton and organic matters in a research area, and an effective method is provided for brittleness evaluation of a shale gas reservoir engineering dessert and organic matter enrichment prediction of a geological dessert.

The invention discloses a fracture parameter multi-objective optimization method for compressed air energy storage of a natural fracture depleted oil reservoir, and belongs to the technical field of oil reservoir engineering and energy storage, and the method comprises the following steps: S1, constructing a double-pore medium numerical model for a matrix-fracture double-pore structure of a natural fracture depleted oil reservoir, analyzing a correlation mechanism of crack parameters and energy storage performance; s2, based on a result of the S1, constructing a multi-target cooperative regulation mathematical model; and S3, solving the multi-target cooperative regulation mathematical model by adopting an adaptive genetic algorithm, and constructing a staged dynamic regulation strategy penetrating through the whole energy storage period in combination with the operation characteristics of the energy storage system. By optimizing the fracture parameters of the natural fracture depleted oil reservoir, efficient and low-loss storage and recovery of air in the fracture oil reservoir are achieved, the air recovery rate and the controllability of operation of the energy storage system are improved, and the stability of the reservoir structure, the safety of the energy storage process, the long-term economy of the system and the utilization efficiency of renewable energy sources are ensured.

The present application is suitable for oil and gas geophysical exploration field, and provides a shale solid skeleton and organic matter elastic parameter synchronous prediction method, the method comprises the following steps: constructing a petrophysical model representing the elastic modulus of shale reservoir solid skeleton and the elastic modulus of organic matter; developing an inversion method in the well based on the petrophysical model; combining the petrophysical model and the scattering function theory, establishing a reflection coefficient formula linearly characterized by the elastic modulus of shale solid skeleton, the elastic modulus of organic matter and the density parameter; combining the reflection coefficient formula and the Bayesian linear inversion theory, developing a seismic petrophysical inversion method; applying synthetic seismic data, testing and verifying the effectiveness of the seismic petrophysical inversion method constructed in step E; then applied to actual seismic data, predicting the elastic modulus of shale gas reservoir solid skeleton and organic matter in the study area, providing an effective method for the brittleness evaluation of shale gas reservoir engineering sweet spot and the organic matter enrichment prediction of geological sweet spot.

The invention belongs to the technical field of oil and gas reservoir engineering and multiphase seepage dynamic monitoring, relates to a characterization method of seepage behaviors of multiphase fluid in a porous medium, and particularly provides a dynamic construction method of a multiphase displacement capillary pressure-saturation relationship based on nuclear magnetic resonance. Comprising the following steps: S1, acquiring a low-field nuclear magnetic resonance relaxation spectrum of a porous medium in a gas-water two-phase displacement process; s2, determining two-phase fluid interfacial tension, a wetting contact angle and a rock surface relaxation rate; s3, determining the dynamic cut-off relaxation time of the displacement stage; s4, calculating equivalent capillary pressure; the residual water saturation is calculated, and the equivalent capillary pressure is the capillary pressure corresponding to the current displacement stage and is used for constructing a capillary pressure-saturation curve. According to the method, the capillary pressure change in the porous medium can be obtained only through spectral analysis without a centrifugal or mercury injection experiment.

The invention discloses a flood season drought limit water level scheduling operation method responding to drought and flood prevention simultaneously, which comprises the following steps of: 1, preliminarily determining a flood season drought limit water level scheme by adopting a reverse sequence recursion method according to downstream water demand; step 2, identifying key influence factors influencing the flood season drought limit water level scheduling application mode of the reservoir system in combination with the current scheduling procedure of the reservoir; 3, constructing a standard normal form of a flood season drought limit water level starting opportunity and a scheduling mode of the reservoir system; 4, establishing a reservoir system flood season scheduling simulation model considering drought limit water level application, and performing simulation calculation in combination with a typical year of a flood season extreme event to form a reservoir drought limit water level application scheme capable of coping with different flood season extreme inflow conditions; the method can scientifically and accurately judge the starting opportunity of the drought limit water level of the reservoir on the premise of guaranteeing flood control safety of a hub and a drainage basin, and is suitable for reservoir engineering which simultaneously undertakes flood control and drought control tasks.

The invention relates to the technical field of gas reservoir engineering and development, in particular to a dynamic correction method for the storage capacity of a gas storage of a condensate gas reservoir. Comprising the following specific steps: S1, based on a gas reservoir engineering method and geological data, calculating an original gas-bearing pore volume of a gas storage, and constructing an initial material balance model and various key parameters related to the initial material balance model; according to the method, through basic data collection and model construction, experimental determination and multi-path pore volume change calculation, and then model correction, parameter review, experimental simulation and final prediction and optimization, the storage capacity related parameters can be accurately calculated and corrected, the influence of various factors on the pore volume is effectively quantified, and the calculation efficiency is improved. Accurate prediction of the storage capacity change of the gas storage under future multi-cycle injection and production is achieved, injection and production parameters are optimized to remarkably improve the working gas amount and the storage capacity utilization rate, and good economic benefits and gas storage operation benefits are brought.

This invention provides a method and computer equipment for determining the dynamic reserves of condensate gas reservoirs, belonging to the field of oil and gas reservoir engineering. The method for determining the dynamic reserves of condensate gas reservoirs includes: acquiring a set of dynamic production data from well pressure measurement of the target condensate gas reservoir; converting the oil production data in the set of dynamic production data to obtain a total converted dynamic production data set of well pressure measurement; acquiring the pseudo-pressure of the target condensate gas reservoir under original conditions; selecting dynamic production data from well pressure measurement at multiple different pressure measurement time points that meet preset conditions to obtain a production indicator curve for the total converted cumulative gas production volume of the target condensate gas reservoir based on the pseudo-pressure; adjusting the production indicator curve for the total converted cumulative gas production volume of the target condensate gas reservoir to obtain an adjusted production indicator curve for the total converted cumulative gas production volume of the target condensate gas reservoir based on the adjusted production indicator curve for the total converted cumulative gas production volume of the target condensate gas reservoir; and calculating the dynamic reserves of the target condensate gas reservoir based on the adjusted production indicator curve for the total converted cumulative gas production volume of the target condensate gas reservoir.

The invention relates to a water invasion volume quantitative identification method based on a semi-ellipsoid radial seepage model, and belongs to the technical field of oil reservoir engineering. The method comprises the following specific steps that dimensionless time tD and pressure increment delta pj of an oil well are calculated; calculating dynamic reserves without water invasion according to the dynamic data of the oil well and a flowing substance balance equation; calculating a water invasion coefficient; the water invasion volume is obtained. The invention relates to a novel method for calculating invasion volumes of different types of water bodies invaded into an oil reservoir by radial flow edge and bottom water by utilizing a semi-ellipsoid geometric model of a Van Everdex-Hust equation principle, which can solve the problem of quantification of the invasion volumes of the water bodies at any moment in the water invasion process of the edge and bottom water oil reservoir. The influence of unstable seepage on the water invasion process is considered, the basic law of fluid flowing in the water invasion process is met, meanwhile, the water invasion coefficient calculation method which does not need to estimate the size of an oil reservoir is provided, and the overall error is small.

The application discloses a kind of well group control reserves chemical flooding sweep efficiency calculation method, comprising the following steps: (1), three-dimensional fine porosity and permeability model is established;(2), well group control reserves chemical flooding sweep efficiency calculation.This method can improve the accuracy of well group control reserves chemical flooding sweep efficiency calculation, so as to provide accurate basis for chemical flooding reservoir engineering design, numerical simulation accuracy, tracking adjustment and post-evaluation of implementation effect of scheme.Compared with the traditional chemical flooding sweep efficiency calculation, the method is more scientific, the concept is clearer, the index is more quantitative, and the chemical flooding sweep efficiency calculation result is more accurate and reliable, which has important significance for guiding oilfield production and development.

The invention discloses a multi-scale analysis-based gas-water seepage field simulation method, which specifically comprises the following steps of: based on a digital rock core reconstructed by a CT (Computed Tomography) scanning image of a typical rock sample of a target reservoir, adopting a microcosmic pore network flow simulation technology; the change rule of the stratum seepage capacity in different stratum pressure gradients and water drive processes, the use degree of a pore network and the water drive process in a pore are calculated, and then a correlation chart with the rock permeability and the pressure gradients is established and used for rapid measurement and calculation of the actual reserve use degree and the recovery degree of the water-invaded sandstone gas reservoir. The method starts from a rock microcosmic pore channel, the scale is amplified to a macroscopic oil reservoir during application, the method has the cross-scale characteristic, and the method is used for rapidly measuring, calculating and evaluating the reserve utilization degree and the recovery degree of the actual water-invaded sandstone gas reservoir and is beneficial to rapid development of the gas reservoir engineering scheme design in a mine field.

The invention provides a numerical simulation-based closed cored well saturation correction method. The correction method comprises the following steps of: S1, establishing a typical rock core numerical simulation model with various physical properties; s2, respectively calculating attribute parameters of the plurality of core models; s3, converting state parameters of the rock core model in an original stratum state into a ground state; s4, calculating the residual oil saturation after the core model simulates the coring loss in a ground state; and S5, establishing a function relationship between the oil saturation of the original stratum state of the core model and the residual oil saturation of the ground state after coring loss under various reservoir physical property conditions. Closed coring well saturation correction is achieved, a foundation is laid for reservoir engineering analysis, a water-oil displacement theory, reservoir development scheme compilation and reservoir dynamic analysis and development adjustment, and the method has important basic significance for oilfield development practice.

The invention relates to a cooperative processing method for a reservoir project operation management task and a model manager thereof, and aims to realize optimization of a task allocation strategy by dynamically adjusting performance requirements and task excitation of asynchronous subtasks in combination with computing power of nodes and real-time asynchronous subtask progress so as to improve the task allocation efficiency. Therefore, the problems of large response delay and low resource utilization rate in a traditional centralized management mode are solved, and the method has the advantages of dynamically adjusting the task allocation strategy, optimizing the resource utilization rate, improving the task cooperation efficiency and shortening the overall task completion time.

The invention discloses a tight gas well unstable open-flow capacity evaluation method based on production dynamic data, and belongs to the technical field of gas reservoir engineering. The method comprises the following steps: firstly, collecting tight gas well production dynamic data and basic parameters and preprocessing; then, a deconvolution algorithm and a Duhamel principle are introduced, and variable-yield variable-pressure data are standardized into constant-pressure variable-yield data; then, in combination with a gas reservoir seepage differential equation considering natural gas compressibility, a'bottom hole flowing pressure-yield-time 'relation model is established; a yield-time function is reversely deduced, the bottom hole flowing pressure is made to be 0, and the unstable open-flow capacity is calculated; and finally, drawing a change curve, analyzing a dynamic rule and a decline mechanism, and providing reference for development countermeasures. The method realizes efficient utilization of production dynamic data, accurately captures an open-flow capacity decline rule, improves evaluation precision and timeliness, reduces cost, is suitable for unconventional gas reservoirs such as tight gas reservoirs, and provides support for efficient development of the gas reservoirs.

Disclosed are a system and a method for training reservoir engineers based on digital twin technology. The training system includes a data operation workstation, a data distribution server and an intelligent terminal; trainees view initial data of reservoir geology by the intelligent terminal to form a preliminary understanding of the reservoir, and then issue reservoir development instructions; according to the development instructions, the reservoir numerical simulation operation module sends feedback data to the intelligent terminal after simulation calculation for the trainees to view, and the trainees analyze and determine reservoir feedback information, thereby forming a new understanding of the reservoir. After having updated understanding of the reservoir, the trainees issue a reservoir development instruction again by the intelligent terminal until the oil and gas field development is completed. After completion, the data operation workstation outputs recovery factor and profit amount of this development simulated by the trainees as simulation results.

The application relates to the technical field of oil reservoir engineering, and is a stratum collapse pressure measuring and calculating method and device combining seismic wave velocity and fault effect, the method comprising the following steps: obtaining the depth pressure and the ratio of transverse wave velocity to longitudinal wave velocity of a target drilling well; establishing a collapse pressure calculation formula according to the relationship among the collapse pressure, the depth pressure and the structural influence; and measuring and calculating the stratum collapse pressure according to the depth pressure, the ratio of transverse wave velocity to longitudinal wave velocity and the collapse pressure calculation formula. The application deeply excavates the petrophysical characteristics of seismic wave velocity reaction, expresses the stratum stress balance state by using the fault activity effect, replaces the complex and difficult-to-measure rock elastic parameters in the traditional Mohr-Coulomb criterion by the ratio of transverse wave velocity to longitudinal wave velocity and the fault effect parameter, greatly simplifies the calculation process, significantly reduces the parameter acquisition difficulty, and has multiple advantages of simple operation, strong timeliness, high calculation efficiency and high accuracy, thereby providing an innovative solution for the rapid and accurate measurement of the stratum collapse pressure in the drilling engineering.

The invention provides a gas well productivity and EUR optimization method in the middle and later periods of dense low-permeability gas reservoir development, and relates to the technical field of gas reservoir engineering, and the method comprises the steps: collecting historical dynamic and static data of a dense low-permeability gas reservoir, and constructing index system data; based on the index system data, static and dynamic main control factor analysis influencing open flow capacity and recoverable reserves is carried out, and a main control factor set is obtained; according to the main control factor set, using a machine learning algorithm to construct a prediction model used for predicting open flow capacity and recoverable reserves; taking open flow capacity or recoverable reserve maximization as a target, and constructing a control optimization model for optimizing production control variables; and for the target well, using the prediction model to predict open flow capacity and recoverable reserves, and using the control optimization model to optimize production control variables. Compared with a traditional productivity analysis method, the method has the advantages that subjective factor interference is effectively reduced, the analysis process is more objective and efficient, and productivity and EUR evaluation under the interaction of different factors is achieved at the same time.

This invention relates to the field of reservoir engineering management technology, specifically a reservoir lifecycle management system based on spatiotemporal matrix and digital twin. The system includes a digital twin model construction module, a spatiotemporal matrix module, a data fusion module, a lifecycle simulation module, a real-time data acquisition and update module, a model dynamic adjustment module, and a management decision support module. The system uses a spatiotemporal matrix to uniformly organize and manage multi-source data throughout the reservoir's lifecycle, utilizes a digital twin model to construct a virtual representation of the reservoir, achieves bidirectional synchronization through data fusion, and dynamically adjusts model parameters based on real-time data, ultimately generating lifecycle management decision outputs. This invention solves the problems of scattered data and static models in existing technologies, improving the accuracy and reliability of reservoir management.

The application relates to the technical field of hydraulic engineering, and discloses a loess hilly area reservoir building method, which aims at the problems of dam site scarcity, low efficiency of water and soil resource development, dispersion of existing water storage projects, prominent contradiction between ecology and culture protection and the like in loess hilly areas, takes global planning and systematic management as cores, realizes organic unification of intensive water resource utilization, comprehensive benefit expansion and ecological protection through a five-step method of scheme optimization comparison, building of large reservoirs and merging of small reservoirs, function zoning, series connection of new and old projects and overall planning of ecology and culture. The method solves the pain points of high building cost, many immigrants and low benefit of reservoirs in loess hilly areas through innovative means such as multi-scheme optimization comparison, function zoning of one reservoir with two systems, reservoir excavation and reconstruction technology, land lifting and regulation and historical culture protection, and can be widely applied to reservoir engineering construction in loess hilly areas.

A well network deployment method for increasing the storage capacity of water-flooded high-permeability gas storage facilities, belonging to the field of oil reservoir gas storage construction technology, includes the following steps: S1, employing oil and gas reservoir fine description technology; S2, employing oil and gas reservoir engineering technology; S3, employing gas storage dynamic analysis technology; S4, establishing a comprehensive geological model, and combining steps S2 and S3 to clarify the direction of seepage dominance and delineate seepage zones in oil and gas areas. This invention, under conditions of high well network control and severe water intrusion and gas channeling, can significantly increase the storage capacity of water-flooded areas, solve the common problem of uneven injection-production displacement in sandstone gas storage facilities, and alleviate the contradiction of large differences in displacement effects between favorable and unfavorable areas during cyclic injection-production. This invention can be applied to the expansion of gas storage facilities that have been renovated due to significant seepage dominance or strong planar heterogeneity.

The present disclosure relates to a kind of water deep penetration guide seam fracturing reservoir engineering design methods, comprising: using water deep penetration perforation method, drill open horizontal long hole in the top of thick oil layer, the horizontal long hole is drilled in low water content direction on plane, and drainage channel is formed in the part where water drive oil capacity is weak;The penetration length of the water deep penetration perforation is determined according to the development thickness of oil layer, injection-production connection relationship, injection-production distance, the number of perforation is in the same direction on the top of each subdivision layer blocked by interlayer, and it is 0.2-0.4m away from upper barrier or interlayer;After the water deep penetration perforation, hydraulic fracturing is carried out to form artificial fracture, let the drilled horizontal long hole guide the longitudinal position and horizontal trend of artificial fracture, to improve the flow conductivity again, realize the purpose of "targeting" tapping of remaining oil enrichment site in the cubic of injection-production well positive rhythm oil layer.

The invention provides a water breakthrough time prediction method and device for an oil well in a deepwater oil reservoir, and relates to the technical field of oil reservoir engineering. Establishing a target function of the dynamic relative permeability of the rock core in the deep water reservoir and the displacement speed and water saturation of the rock core; determining the derivative of the target function at the water saturation of the water drive front; and predicting the water breakthrough time of the oil well in the deepwater reservoir according to the derivative, the static pressure of the deepwater reservoir, the formation pressure of the deepwater reservoir, the porosity of the reservoir in the deepwater reservoir, the pore volume in the seepage region between the injection wells and the production wells, the target water injection rate of the oil well and a target formula. Therefore, on one hand, the influence of the dynamic relative permeability on the water breakthrough time is considered, the accuracy of water breakthrough time prediction is improved, on the other hand, the waterless oil production period of the oil well is prolonged, the accumulated oil production and the recovery efficiency of the oil well are improved, and a basis is provided for subsequent development and adjustment.

The invention belongs to the technical field of reservoir engineering application, and discloses a digital-analog characterization method for reservoir pressure drive seepage parameters, which comprises the following steps: S1, measuring the permeability and relative permeability of a stratum sample before pressure drive, manufacturing artificial microfractures in a reservoir, converting original stratum pore seepage into artificial fracture net seepage, and calculating the permeability of the stratum sample before pressure drive; performing a water injection experiment on the sample by adopting different displacement pressure gradients, and determining the change relation of the permeability of the reservoir sample along with the pressure and the change condition of relative permeability before and after the matrix fracture pressure is reached in the water injection experiment process; s2, calculating the limit wave and radius under the pressure-driven water injection condition; and S3, carrying out digital-analog characterization on the oil reservoir pressure-drive water injection seepage parameters. According to the method, the permeability and relative permeability parameters are adjusted in real time by using the pressure as a reference condition, and full-life-cycle seepage parameter characterization in the pressure driving process is equivalently completed.

The invention relates to the technical field of hydraulic engineering, in particular to a reservoir engineering safety management system and method, and the method comprises the steps: obtaining a fracture tomographic image of a drainage gallery wall through a through-wall ground penetrating radar, and synchronously collecting the infiltration linear displacement dynamic data of a distributed optical fiber sensor; performing space-time alignment on the two types of data, constructing a fracture space topological relation and seepage conduction path model, and generating a defect-seepage coupling map; a coupling atlas analysis module and a space-time convolutional neural network module are used for identifying the sudden change trend of the displacement rate of the infiltration line, and a gallery structure failure early warning signal is triggered; after early warning, a reinforcement work order is automatically generated, the unmanned aerial vehicle is called to carry out a high-definition image rechecking task, a rechecking result is fed back to correct the seepage conduction path model, and dynamic self-correction is achieved. The method has the capabilities of accurate modeling, intelligent early warning and real-time closed-loop regulation and control, and can significantly improve the structural safety management level of reservoir engineering.

The invention provides a reservoir spillway flood regulation calculation method and device and electronic equipment, and the method comprises the steps: firstly selecting a reservoir original design flood hydrograph of a frequency corresponding to a target standard, then selecting a gate control working condition of a reservoir spillway, and carrying out the regulation calculation of the flood of the reservoir spillway based on the reservoir original design flood hydrograph and a reservoir original discharge capacity curve; and determining a reservoir design flood hydrograph and a reservoir discharge capacity curve corresponding to the gate control working condition, and then performing flood regulation calculation by adopting a water balance method based on the gate control working condition, the reservoir design flood hydrograph, the reservoir discharge capacity curve, the normal storage level of the reservoir and the water level storage capacity curve of the reservoir to obtain a reservoir flood regulation hydrograph. By adopting the method, the efficiency and the accuracy of reservoir flood regulation calculation can be improved, so that the working efficiency of reservoir project spillway type comparison and selection can be improved.

The application discloses a reservoir scheduling agent training method, comprising the following steps: determining global state information of a reservoir group and local state data of a target reservoir based on historical actual hydrological data and historical predicted runoff data; determining first actual discharge data and predicted water quantity data of the target reservoir through a reservoir scheduling agent based on the local state data and reservoir engineering attributes; determining a joint decision score corresponding to the reservoir scheduling agent based on the local state data and the first actual discharge data; determining a collaborative total penalty term and a penalty gradient update rule of the reservoir scheduling agent based on the predicted water quantity data, the local state data and the first actual discharge data; and iteratively optimizing the reservoir scheduling agent based on the joint decision score, the collaborative total penalty term and the penalty gradient update rule until the reservoir scheduling agent meets a preset convergence condition. Through multi-scale collaborative training of the reservoir scheduling agent, the decision accuracy is improved.