172 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 belongs to the technical field of shale oil horizontal well three-dimensional development, and particularly discloses a shale oil three-dimensional well network well location multi-objective optimization method which is used for solving the problem of how to achieve multi-objective collaborative optimization of the recovery ratio, the economic benefit and the inter-well interference degree. Comprising the following steps: (1) constructing a multi-field coupling dynamic oil drainage volume characterization model; (2) establishing an inter-well interference degree quantitative evaluation system based on the dynamic oil drainage volume characterization model; (3) realizing multi-source data fusion and high-precision prediction on the dynamic oil drainage volume, the recovery ratio, the net present value and the inter-well interference degree by combining a CNN-LSTM deep learning prediction model; and (4) implementing multi-objective optimization based on an NSGA-III multi-objective optimization algorithm, and comprehensively balancing the recovery ratio, the net present value and the inter-well interference degree on the premise of meeting engineering and economic constraints. Reliable technical support is provided for decision deployment of oil reservoir engineers under complex development conditions.

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 an oil reservoir polymer flooding process oil-water distribution simulation method and device based on a cellular automaton, equipment, a medium and a product, and relates to the field of oil reservoir engineering and seepage mechanics. The method comprises the steps that rectangular grid division is conducted on an oil reservoir space, three-dimensional coordinates of cellular nodes are determined, and a cellular automaton model is constructed; according to the polymer oil displacement scheme parameters, oil reservoir state parameters at the end moment of water displacement are initialized, and boundary conditions of the mole-type cellular automaton model are established; making an evolution rule for each neighborhood cellular node in the Moire cellular automaton model; according to a numerical value stability rule, adjusting parameters of each neighborhood cellular node in the Mohr-type cellular automaton model; according to the method, a relative permeability nonlinear regulation and control rule is formulated for the Mohr-type cellular automaton model to simulate oil-water distribution in the oil reservoir polymer flooding process of the Mohr-type cellular automaton model, the starting pressure gradient is accurately simulated, and the low-permeability oil reservoir evolution process is accurately described.

The invention relates to the technical field of reservoir engineering, and discloses a physical information neural network numerical simulation method suitable for a low-permeability water-drive reservoir, and the method comprises the steps: employing a finite volume method for full implicit solution, and considering strong nonlinear seepage; an expert experience loss function is constructed, the pressure saturation output range is limited, and the solving efficiency is improved; a full-connection neural network is adopted as a basis, and adjacent position anchoring, a self-adaptive activation function and a jump connection gating updating structure are added; respectively solving pressure and saturation by using two independent networks; introducing a well model to process a large pressure gradient problem; and substituting the pressure and saturation calculated by the network into a loss function to carry out back propagation to optimize the network. The method has high prediction precision when processing complex problems such as large capillary pressure and non-linear seepage, the problem that an existing physical information neural network is difficult to adapt to low-permeability water drive reservoir numerical simulation is effectively solved, and the whole training process does not need to depend on any label data.

The invention belongs to the technical field of oil and gas field intelligent development and research, and particularly relates to a construction method of an enhanced oil production technology intelligent screening decision model based on improved Stacking, and the method specifically comprises the following steps: 1, collecting global enhanced oil production project data which has been successfully implemented, and forming a complete data set through data processing and analysis; 2, multiple conventional machine learning algorithms are selected, and multiple enhanced oil extraction technology intelligent screening models based on the conventional machine learning algorithms are constructed; step 3, performing fusion by using Stacking ensemble learning to construct a Stacking-based enhanced oil extraction technology intelligent screening model; and step 4, improving Stacking through the newly added meta-model, and constructing the enhanced oil extraction technology intelligent screening integration model based on the improved Stacking. According to the method, the limitation of a machine learning algorithm in enhanced oil production technology screening decision is solved, and more accurate decision support is provided for oil reservoir engineers.

The present invention comprises a computer-implemented method for automating the co-registration of SEM and 3D microtomography images in rock sample cylinders, characterized by comprising three main steps: (i) image pre-processing; (ii) internal orthogonal search; (iii) external multi-angle search. The method plays a fundamental role in the creation of image pairs. These pairs capture the same region of the rock, but with different analytical properties. Thus, the co-registration between 2D microscopy and 3D tomographic data provides a fundamental basis for the application of machine learning techniques and the expansion of the originally planar mineralogy to the entire three-dimensional volume. The three-dimensional mineralogical model generated from this co-registration has fundamental implications for the creation of digital rock models. The automation of the co-registration process between these acquisitions contributes to the advancement of petroleum engineering, since co-registration accelerates the process of generating image pairs for the use of machine learning algorithms in the generation of the three-dimensional mineralogical model. This method, in its turn, has direct application both in oil reservoir engineering and in geological interpretation.

The invention provides a standardized management method and system for reservoir engineering, and belongs to the technical field of water conservancy project management, and the method comprises the steps: carrying out the processing of multi-dimensional data obtained by a sensor based on a first random forest model, and obtaining the target state data of a target reservoir dam body, the multi-dimensional data comprises structural data and monitoring data of the target reservoir dam body; performing feature extraction on the target state data to obtain target state feature data, obtaining a target similarity based on multiple similarities between the target state feature data and each piece of state feature data in a state library, and selecting a target state of the target reservoir dam body from the state library based on the target similarity; and determining a corresponding target management strategy based on the target state. According to the invention, the method and system can accurately recognize the state of the reservoir dam body, reflect the change trend of the structure of the reservoir dam body in real time, adjust the management strategy according to the state of the reservoir dam body, and achieve the risk prevention and control of the reservoir dam body.

The invention relates to the technical field of natural gas underground storage, gas reservoir engineering and indoor experiments, and particularly discloses a method and device for calculating the gas storage capacity of an aquifer gas storage. Dividing the pore volume occupied by the gas reservoir reserves of the water-bearing stratum underground gas storage into accumulated water yield, water body elastic compression amount, the pore volume contributed by rock pore swelling amount and the volume of gas dissolved in formation water; calculating cumulative water yield, residual water elastic compression amount, pore volume contributed by rock pore swelling amount and volume of gas dissolved in formation water in sequence; and according to the pore volume of gas storage and the volume of gas dissolved in formation water, the gas storage capacity of the aquifer gas storage under the set injection-production pressure condition is determined. According to the method provided by the invention, the calculation precision of the gas storage capacity of the aquifer gas storage is greatly 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 relates to the technical field of water conservancy projects, in particular to a method for predicting the crack occurrence risk of an earth and rockfill dam through settlement monitoring data, the high, medium and low risk levels of a dam body are comprehensively judged by calculating and analyzing the vertical displacement rate, the settlement rule, the longitudinal inclination, the longitudinal tensile strain and the settlement rate, and the crack occurrence risk is predicted through the method. The method can prompt patrol key points, find potential safety hazards in advance, prevent dangerous cases such as landslide and collapse, provide technical support for reservoir safety identification, risk removal reinforcement and operation management, provide technical schemes for digital reservoir construction, and guarantee safe operation of reservoir engineering.

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 relates to a flood wave classification evolution characteristic calculation method and system and a medium. The method comprises the following specific steps: collecting reservoir operation data and long-series hydrological data of important control stations of a river channel; according to the flood routing characteristics of the reservoir-river channel class, the similar flood process of the downstream of the reservoir is judged; judging whether the flood routing process of each control site of the river channel is influenced by the jacking of the water level of the downstream reservoir or not according to the flood routing characteristics of the river channel-reservoir class; based on the reservoir dispatching regulation and the reservoir engineering characteristics, analyzing whether the historical typical reservoir drainage mode meets the flood wave classification requirement or not; a control variable method is adopted to analyze the relationship between evolution characteristics such as flood peak evolution duration, a tanning coefficient and rising response time and elements such as initial reservoir outbound flow, maximum rise of the reservoir outbound flow, the increase rate of the reservoir outbound flow, maximum duration of the reservoir outbound flow and the water level of the reservoir, and a correlation curve is constructed. According to the invention, specific analysis of flood routing in various flood routing scenes is realized.

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 discloses a method for judging the full life cycle production stage of a horizontal tight gas well, and belongs to the field of gas reservoir engineering. For a horizontal tight gas well, a seepage mathematical model considering multiple sections of fracturing cracks is constructed, model solving is achieved through a semi-analytical method, a gas well full-life-cycle seepage law curve with pressure and a pressure derivative curve as reference is drawn, and a judgment method for dividing different life stages is established according to curve characteristics. According to the method, main control factors influencing occurrence and ending of life stages are defined, and a calculation method for occurrence time of each life stage is constructed, so that the life stage of the horizontal tight gas well and the future development life of the horizontal tight gas well are evaluated, and a theoretical reference is provided for efficient development of tight gas reservoirs.

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 present invention provides a method for quantitatively evaluating the sweet spot quality of conglomerate horizontal wells based on logging-while-drilling (LWD) data. Because some wells lack completion electrical logging data and dipole acoustic wave data, density, P-wave transit time, and S-wave transit time data cannot be directly obtained. LWD and gas logging data must be used to model and effectively model density, acoustic wave, and S-wave transit time. Based on the calculated density, acoustic wave, and S-wave transit time, geological parameters such as porosity, saturation, and permeability can be calculated. Based on S-wave transit time, density, and P-wave transit time, reservoir engineering parameters such as Young's modulus, Poisson's ratio, brittleness index, and maximum and minimum principal stresses can be calculated. The quality of the horizontal well sweet spot can be quantitatively evaluated by comprehensively utilizing the geological sweet spot and engineering sweet spot parameters.

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 relates to the technical field of oil reservoir engineering, in particular to a horizontal well position auxiliary screening method and computer equipment. The horizontal well position auxiliary screening method comprises the following steps that oil reservoir production potential data are obtained; calculating the reservoir production potential data by using a horizontal well position auxiliary screening algorithm to obtain a horizontal well position preliminary screening result; and unreasonable well positions in the horizontal well position primary screening result are removed, and a well position screening result is obtained. The method comprises the following steps: calculating oil reservoir production potential data by using a horizontal well position auxiliary screening algorithm to obtain a horizontal well position preliminary screening result; and screening the horizontal well position preliminary screening result, and further removing unreasonable well positions in the horizontal well position preliminary screening result, so as to obtain a well position screening result. By means of the method, the horizontal well position can be rapidly screened out from the oil reservoir production potential data, rapid auxiliary screening of the horizontal well position is achieved, the calculation complexity is greatly reduced, and the calculation efficiency is improved.

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 embodiment of the present application discloses an application method, device, terminal and storage medium of a binomial production capacity equation, which belongs to the field of gas reservoir engineering for natural gas extraction. The application method of the binomial production capacity equation provided in the present embodiment is that the terminal can process the historical well test data according to the linear regression analysis method to obtain a binomial production capacity method, and at the same time obtain the binomial relationship that conforms to the physical environment parameters of the target gas well. Combining the above binomial production capacity method and the binomial relationship, the production capacity parameters of the target gas well can be obtained, wherein the parameters finally obtained can indicate the natural gas generation capacity of the target gas well. Since the above process can avoid the use of complex professional engineering software to calculate the production capacity parameters, the embodiment of the present application has the function of reducing the calculation complexity of the production capacity parameters, and at the same time can ensure the closeness of the production capacity parameters to the actual data.

The invention discloses an anti-seepage method in a karst depression catchment reservoir-forming project, which adopts a grouting curtain combined underground river plugging measure, and comprises the following steps: 1) collecting hydraulic parameters; 2) underground river slope calculation: based on the hydraulic parameters and the difference between the underground river outlet flow velocity and the underground river inlet flow velocity, adopting different methods to calculate the underground river overall slope; (3) determining the position of an upper layer grouting tunnel; 4) determining an underground river plugging position based on the slope; 5) calculating the height of the grouting curtain based on the slope; according to the anti-seepage method in the karst depression catchment reservoir forming project, determination of key parameters in construction is improved, the anti-seepage construction precision and the construction efficiency can be improved, and the construction cost is saved.