147 results about "Reservoir simulation" patented technology

A method of optimizing a set of oil producing wells to be drilled in a reservoir includes receiving a base reservoir simulation representative of a geological oil reservoir, clustering the reservoir, and generating, in a first process, a possible pool of well positions in the reservoir, where each well position satisfies plausibility and respects operational constraints. The method further includes, in a second process, optimizing the pool of well positions, the second process maximizing a dynamic variable of the reservoir, and outputting the optimized pool of wells to a user. In embodiments, the second process further includes training a DNN surrogate model to forecast the production of the reservoir; and using the trained DNN surrogate model, optimizing the pool of wells.

The invention provides a CO2 sequestration simulation method based on transfer learning and a physical information neural network, which aims at a geological carbon dioxide sequestration process by combining the transfer learning and the physical information neural network, and comprises the following steps of: simulating and generating data by using a Matlab oil reservoir simulation tool box, and constructing a neural network basic model; the physical law of carbon dioxide migration in the porous medium is trained and learned through coarse resolution, then fine tuning is performed on the generated actual geological model data by adopting a migration learning strategy to adapt to different geological structures and injection conditions, and a neural network loss function is embedded in combination with a Darwest equation and a mass conservation equation to obtain a carbon dioxide migration model. Compared with a traditional numerical simulation method, the method has the advantages that the calculation efficiency is remarkably improved while the prediction precision is kept, and the method is suitable for carbon dioxide sequestration optimization and environmental risk assessment under complex geological conditions and has good industrial popularization value and environmental benefits.

The invention provides an automatic history fitting method for gas drive numerical reservoir simulation, which comprises the following steps of: 1, establishing a gas drive numerical simulation mathematical model, and correcting the gas drive numerical simulation mathematical model by using a gas drive PVT phase state fitting experiment; 2, solving the corrected gas drive numerical simulation mathematical model obtained in the step 1, performing parameter analysis, and screening main control factors influencing accumulated oil production; 3, generating a numerical simulation training sample set based on an orthogonal experiment, and obtaining the main control factor parameter initial value constraint screened out in the step 2 through a machine learning algorithm; step 4, establishing a multi-parameter fitting objective function for realizing historical fitting; and step 5, using the main control factor parameter initial value constraint obtained in the step 3, performing iterative calculation through a projection gradient method, fitting the target function established in the step 4, and terminating when a convergence condition is satisfied. According to the method provided by the invention, the constraint parameter values can be adaptively calculated, automatic historical fitting is completed, and the definition of the fitting parameter range does not depend on empirical and experimental determination any more.

The invention relates to the technical field of hydrofracture simulation experiments, in particular to a true triaxial hydrofracture fault slippage casing deformation monitoring method and system, and the method comprises the steps: preparing a target reservoir simulation sample; arranging and installing a shaft and a sensor; carrying out a water pressure physical model experiment and recording experiment data; and analyzing and processing the experimental data, and performing quantitative evaluation by combining the final state of the target reservoir simulation sample. According to the method, the shear deformation influence of fault slippage on the shaft casing under the true triaxial hydraulic fracturing condition can be quantitatively evaluated; scientific basis is provided for optimization of fracturing optimization design parameters, and engineering practical significance is achieved for optimization of the horizontal well casing damage prevention and control theory and on-site construction design.

A method may include determining various adaptive weights using a machine-learning model, first simulation data, and second simulation data. The method may further include determining predicted simulation data for a time step of the reservoir simulation using the adaptive weights, the first simulation data, the second simulation data, grid model data, and various reservoir simulation parameters. The method may further include determining whether the predicted simulation data satisfies a predetermined criterion. The method may further include determining, in response to determining that the predicted simulation data fails to satisfy the predetermined criterion, updated simulation data for the time step of the reservoir simulation based on the predicted simulation data, the grid model data, the reservoir simulation parameters, a search method, and the reservoir equations.

The invention discloses a new method for constructing an oil reservoir simulation agent model based on transfer learning, and relates to the technical field of petroleum engineering, and the method comprises the steps: building a fine-scale oil reservoir model; constructing a high-fidelity data set; carrying out scale upgrading and coarsening on the oil reservoir model; constructing a low-fidelity data set; constructing a deep learning model; training a pre-training model by using the low-fidelity data; finely tuning the pre-training model by using the high-fidelity data; and predicting output parameters. According to the method, it can be guaranteed that under the condition that a small amount of high-fidelity training data is used, oil reservoir multi-term flow under the variable well control condition can be accurately predicted, dependence on the high-fidelity training data in the agent model building process is effectively reduced, and the agent model building time is shortened on the premise that prediction precision is not affected. According to the method, the embedded module is introduced to process the time-varying well control parameters, the problem that matrix element parameters corresponding to well positions are difficult to effectively diffuse to the whole output result through finite times of convolution is solved, and the global influence of the well control parameters on the output result of the proxy model is improved.

The invention provides a tight gas and deep coal bed gas collaborative exploitation simulation experiment device. The tight gas and deep coal bed gas collaborative exploitation simulation experiment device is composed of a shaft simulation device, a reservoir simulation device, a gas-liquid two-phase flow supply device and a control system. The casing pipe is provided with a plurality of transparent converging sections, and the oil pipe can be downwards inserted to different layers. And the gas-liquid two-phase flow supply device is provided with a plurality of groups of independent gas-liquid conveying manifolds which are respectively connected with each convergence section of the sleeve through the reservoir simulation device, so that the independent regulation and control of seepage parameters and production pressure difference of each layer are realized. The control system integrates pressure and flow acquisition and image recording functions, monitors and analyzes data in real time, is used for simulating an interlayer coupling relationship, a mutual interference mechanism and dynamic productivity response during multi-layer commingling production, and provides an experimental basis for collaborative production layer strategy optimization.

The invention discloses an oil and gas reservoir simulation method and device, a storage medium and equipment, and belongs to the technical field of oil and gas field development. Comprising the steps of S1, constructing a data set; the data set comprises parameter data of all wells in the target block, and the parameter data comprises all attribute types of an original data file of the target block; s2, constructing a deep learning model; the deep learning model comprises an encoder, a converter and a decoder, features of input data are extracted through the encoder, time evolution is carried out through the converter, and dynamic field change and well response change conditions are reconstructed through the decoder; s3, training the deep learning model through the data set; and S4, obtaining to-be-predicted parameter data and inputting the to-be-predicted parameter data into the trained deep learning model to obtain an oil and gas reservoir simulation result. The method solves the problem of prediction of the production dynamics of oil and gas reservoirs with different sizes and different numbers, and improves the accuracy and application range of the deep learning model.

The invention belongs to the technical field of oil development hydraulic fracturing, and discloses an artificial fracture flow conductivity evolution process prediction method considering a dynamic crustal stress field, and the method specifically comprises the following steps: constructing an oil reservoir geologic model; constructing an oil reservoir geomechanical model; carrying out a proppant long-term conductivity test experiment to obtain a proppant conductivity chart; and based on the constructed oil reservoir geologic model and the constructed geomechanical model, combining proppant flow conductivity chart data, and utilizing a fluid-solid coupling oil reservoir simulation technology to predict a reservoir stress field and a pore pressure field in the fracturing production process, so as to predict fracture flow conductivity in different production stages. According to the method, the fracture flow conductivity change under the production dynamic state can be more comprehensively represented, so that a support is provided for fracture flow conductivity optimization of a fractured well and proppant type selection.

The invention provides a heavy oil thermal-flow coupling development experimental device and method based on microwave-assisted gravity drainage, and belongs to the field of oil-gas field development. The experimental device comprises a three-dimensional oil reservoir simulation system, a microwave-assisted heating system, a horizontal well injection-production regulation and control system and a multi-field monitoring system; the microwave auxiliary heating system comprises a microwave generation regulation and control system, a microwave transmission system and a shaft integrated microwave radiator, the microwave generation regulation and control system comprises an industrial grade microwave generator, a power regulator and a PLC, and the microwave transmission system comprises a microwave coaxial cable and a microwave waveguide tube bundle; and the microwave generator is continuously connected with the microwave waveguide tube bundle and the shaft integrated microwave radiator. According to the heavy oil thermal-flow coupling development experimental device and method based on microwave-assisted gravity oil drainage, the technical problems that an existing deep heavy oil thermal recovery experimental device cannot reproduce a'thermal-flow-force 'multi-field coupling environment, the microwave heating adaptability is poor, and the experimental scale and the field deviation is large are solved. The heavy oil thermal-flow coupling development experimental device and method based on microwave-assisted gravity oil drainage solve the technical problems that an existing deep heavy oil thermal recovery experimental device cannot reproduce the'thermal-flow-force' multi-field coupling environment.

The invention belongs to the technical field of sand control well completion in the natural gas hydrate development industry, and particularly relates to a natural gas hydrate reservoir gravel packing sand control long-period simulation experiment device and a sand control chart construction method. The simulation experiment device comprises a sand production and prevention and control integrated simulation system, a fluid injection system, a confining pressure pump, a liquid recovery tank and a data acquisition system, wherein the sand production and prevention and control integrated simulation system comprises a reservoir simulation module, a shaft annulus gravel layer simulation module and a screen pipe pre-filling layer simulation module; the fluid injection system and the confining pressure pump are connected with the reservoir simulation module, the liquid recovery tank is connected with the screen pipe pre-filling layer simulation module, and the data acquisition system is in signal connection with the sand production and prevention and control integrated simulation system. The simulation experiment device designed by the invention can truly simulate different production working conditions of the hydrate well, can accurately simulate the structure of the hydrate well bottom gravel packing sand control system, and can truly reduce the flow process of the hydrate well bottom fluid, so that the obtained experiment result is more authentic.

Method and systems for generating a reservoir simulation grid for a subterranean reservoir are disclosed. The method may include, using a reservoir simulation system, to obtain a reservoir model, where the reservoir model comprises a plurality of wellbore trajectories, define a coarse simulation grid pertaining to, at least a portion, of the reservoir model, and determine a grid refinement field based, at least in part, on the reservoir model. The method may further include, using a reservoir simulation system, to form a tree based on the coarse simulation grid, refine the tree at least in part, on an intersection of the grid refinement field and the coarse simulation grid, and define the reservoir simulation grid based, at least in part, on the refined tree and the coarse simulation grid.

Techniques for modeling a reservoir include identifying or inputting well and reservoir model parameters into a control system; calculating, with the control system, one or more hydraulic fracture limits of one or more hydraulic fractures in the reservoir model; determining, with the control system, one or more fracture segments; performing, with the control system, connection calculations based on the one or more hydraulic fracture limits and one or more fracture segments; setting up, with the control system, connections between the one or more hydraulic fractures and a matrix grid of the reservoir model; performing, with the control system, a reservoir simulation; and outputting, with the control system, reservoir simulation data from the reservoir simulation.

The invention provides an intelligent oil reservoir simulation and safety prediction system. The system comprises a parameter setting module, a numerical simulation software generation module, an oil reservoir simulation and safety prediction module, an information interaction module, an application management module and a program modularization module, the parameter setting module is used for acquiring numerical simulation parameters set by a user from a user side and importing the numerical simulation parameters into the numerical simulation software generation module; configuring numerical simulation parameters in a human-computer interface in the parameter setting module, wherein the numerical simulation parameters comprise well, reservoir, fluid and well network parameters; the well network parameters comprise a well network type, a well group size, a well name and a well number, grid mapping of a well, a position of the well, a control radius of the well, a grid influence range of the well and yield data of the well; and the numerical simulation software generation module combines the obtained numerical simulation parameters with a preset parameterized model and an intelligent optimization algorithm through a neural network model after receiving the numerical simulation parameters.

The invention relates to the technical field of numerical reservoir simulation, in particular to a shale volatile oil reservoir simulation method considering fracturing fluid injection phase change, comprising: acquiring shale volatile oil reservoir development parameters and core data of a target block; the method comprises the following steps: establishing a shale volatile oil reservoir numerical basic simulation model according to shale volatile oil reservoir development parameters, preparing a micro-fluidic chip according to core data, performing pore scale bubble point test, and correcting parameters of the basic simulation model according to bubble point data after fracturing fluid injection; establishing a shale volatile oil reservoir numerical value complete simulation model considering the fracturing fluid injection phase change, and analyzing the influence of the injected fracturing fluid on the oil and gas yield by using the shale volatile oil reservoir numerical value complete simulation model. According to the method, the production rule in the shale volatile oil reservoir exploitation process can be accurately obtained, the numerical simulation method of the shale volatile oil reservoir is perfected, and the method has important significance for guiding efficient development of the shale volatile oil reservoir.

The present disclosure relates to computer-implemented methods, software, and systems for automatically assessing simulation results obtained from simulation to predict production of a reservoir. Simulation results and observed field data can be obtained based on executing a simulation model for predicting production of a reservoir in a field for a period of time. The observed field data is obtained from the field and for the reservoir in production during the period of time. A type of misfit of the simulation model can be determined when predicting the production. The one or more trained classifiers are trained to classify the type of misfit is based on an image processing of the observed field data and the simulation results. A modification is determined for the simulation model to adjust future simulation results to reduce the misfit of the simulation model. The simulation model is adjusted based on the determined modification.

The invention discloses an intelligent simulation method for synchronous expansion of large-section multi-cluster fracturing cracks of a horizontal well, and relates to the technical field of numerical reservoir simulation. The method comprises the following steps that firstly, a prediction model of fracture pressure is established, the fracture pressure of a target well is predicted, and then the total crack initiation cluster number in the fracturing process is obtained; establishing a multi-cluster fracturing crack synchronous expansion simulation model, and discretizing the multi-cluster fracturing crack synchronous expansion simulation model to obtain a discretized model; based on a self-adaptive elite genetic algorithm, firstly, flow distribution results of crack opening positions of all clusters under different time conditions are obtained, and then the three-dimension size of all the clusters of cracks is predicted. According to the method, the expansion condition of the multi-cluster fracturing cracks can be mastered in real time, guidance is provided for fracturing process optimization and construction scheme adjustment, and the recovery efficiency of the horizontal well is effectively improved.

The invention discloses a mine water recharge multi-field coupling effect simulation experiment system and method, and relates to the technical field of mine water utilization. The experimental system comprises a reservoir simulation box, a mine water supply system, a produced water collection and detection system and a microorganism culture and injection system, the reservoir simulation box is provided with a reservoir medium filling area and is matched with the pressure pump and the temperature control jacket to simulate the pressure and temperature of a deep stratum, the mine water supply system provides controllable mine water, the microorganism culture and injection system injects specific microorganisms, and the produced water collection and detection system detects the water quality and microorganism characteristics. The experimental method comprises the following steps: simulating reservoir conditions, injecting mine water and microorganisms, monitoring multi-parameter changes, and establishing a composite blockage mathematical model and a multi-field coupling partial differential equation. According to the invention, five-field coupling simulation of a stress field, a hydrodynamic field and the like can be realized, and a technical means is provided for underground water environment evolution and permeability mechanism research.

The invention belongs to the field of shale oil reservoir development in the oil and gas reservoir development technology, and discloses a pressure-braising-seepage-drainage integrated experimental device and method for shale reservoir actual temperature and pressure conditions, and the device comprises a power system, a fluid supply system, a reservoir simulation system, a temperature control system and an electronic metering system; the power system is used for providing pressure for the fluid supply system; the fluid supply system is used for supplying fluid to the reservoir simulation system, and the fluid is oil in the oil saturation process or fracturing fluid in the displacement process; the reservoir simulation system is used for simulating the fracturing-soaking-imbibition-flowback integrated process of the target shale oil reservoir under the actual temperature and pressure conditions; the temperature control system is used for simulating the actual temperature of the shale reservoir; and the electronic metering system is used for measuring the oil saturation in the produced liquid. The device is resistant to high temperature and high pressure, can simulate the ultrahigh-temperature and high-pressure actual oil reservoir environment of a shale reservoir, and can realize the fracturing-soaking-imbibition-flowback integrated process considering the actual formation pressure of shale.

The invention discloses an oil-water two-phase seepage model construction method and system based on a critical path and a medium. Relates to the technical field of oil-gas field development. According to the scheme, a traditional black oil model simulation technology and a critical radius technology based on a critical path seepage theory are combined, and on the basis of ensuring the scale of an oil reservoir model, the oil-water two-phase seepage characteristic oil reservoir simulation method considering the micro-scale critical path is provided; microscopic characteristics such as a pore throat structure in a real reservoir rock are restored to the greatest extent by using the critical radius, and phenomena such as a dominant channel (critical path) of seepage of oil-water two-phase fluid in a pore throat and factors influencing displacement efficiency are researched from a microscopic perspective, so that a higher-precision oil reservoir simulation analysis result is obtained; according to the scheme, the flow and pressure of each component of oil and water are calculated directly based on the critical radius and the critical path length, a static oil-water relative permeability curve does not need to be input in the simulation process, and the stress state and the change process of each part of the oil reservoir can be reflected more directly.

The embodiment of the invention provides a single-well water channeling shielding type remaining oil quantitative characterization method and system, and belongs to the technical field of oil reservoir simulation. The method comprises the steps that seismic attribute information of a target oil reservoir area is collected, oil and gas filling path analysis is executed based on the seismic attribute information, and whether an oil reservoir is located on an oil and gas filling path or not is judged and researched based on an analysis result; in response to a trigger signal that an oil reservoir is located on an oil and gas filling path, respectively executing karst cave three-dimensional depiction and fracture three-dimensional depiction based on the seismic attribute information to obtain fracture-cave well space structure characteristics; based on the single well exploitation data in the target oil reservoir area, oil and gas exploitation degree analysis is executed, and oil and gas exploitation degree information is obtained; and performing residual oil quantitative characterization based on the space structure characteristics of the fracture-cave well and the oil and gas exploitation degree information, and outputting the space distribution and scale of the residual oil. According to the scheme, the residual oil quantitative characterization is executed based on the fracture-cave well space structure characteristics and the oil and gas exploitation degree information, the space distribution and scale of the residual oil can be output, and important reference is provided for follow-up oil and gas resource management and development.

The invention relates to a buried hill gas storage effective gas storage space evaluation method, and belongs to the technical field of oil-gas exploration. The method comprises the following specific steps: acquiring fracture development parameters; determining the type of a storage space; reservoir logging response characteristics are determined; extracting buried hill cracks; establishing a bedrock geologic model and a bedrock buried hill discrete fracture model of the target area; and importing the results into a gas storage simulation model in the form of data flow, extracting effective gas storage spaces of a substrate and a crack of the buried hill gas storage, and determining a final buried hill building effective gas storage space. Through research on the method for calculating the reservoir space of the buried hill oil and gas reservoir rebuilt gas storage, the problem of invalid reservoir space calculation is deducted, the calculation accuracy is improved, and theoretical support is provided for calculation of the buried hill reservoir building capacity and later injection and production well position deployment.

The utility model discloses a rock core experiment device for simulating oil reservoir environment, which comprises an oil reservoir simulation device, the oil reservoir simulation device comprises a rock core cabin body, a rock core cabin opening is arranged on the top wall of the rock core cabin body, the rock core cabin body is connected with a pressure regulating device, and a rock core base is arranged on the bottom wall in the rock core cabin body. And the core base is in the projection of the core cabin opening. The oil reservoir simulation device can provide temperature, pressure and formation fluid, simulate the real consolidation condition and performance characteristics of the artificial rock core in the formation environment, truly reflect the characteristics of the artificial rock core in the formation environment, provide more real experimental data for sand prevention design, preferably select better products, and improve the production efficiency. The sand prevention effect of chemical sand prevention is improved, and the sand prevention validity period is prolonged.

The present invention relates to the field of oil exploration, in particular to a method for parameter selection on the basis of the migration law of an injected gas for a condensate gas reservoir and an apparatus. The method comprises: according to an injection condition set, constructing a mathematical model for the flow and diffusion of an injected fluid; numeralizing the mathematical model, so as to obtain a relationship curve between a breakthrough time of an injected gas and the Peclet number; constructing a physical simulation model for the displacement of a condensate gas reservoir by the injected fluid, and on the basis of an injection condition, carrying out a condensate gas reservoir simulation experiment, so as to obtain a simulation result; according to the simulation result, verifying and fitting the relationship curve between the breakthrough time of the injected gas, the mobility ratio and the Peclet number, so as to determine a breakthrough time calculation formula; by means of using injection parameter sets, performing condensate gas reservoir gas injection experiments, and calculating the breakthrough time of the condensate gas reservoir gas injection experiment corresponding to each injection parameter set; and determining as optimal injection parameters the injection parameter set corresponding to the condensate gas reservoir gas injection experiment with the shortest breakthrough time. The present solution solves the problem of blockages of oil and gas seepage flow channels of condensate gas reservoirs, thus preventing affects on normal operations of oil and gas wells.

The application provides a method and system for calculating the conductivity of a sand-acid fracturing reservoir simulation system, which comprises the following steps: constructing a simulation parameter combination set around sand-acid fracturing operation parameters for reservoir types with sand-acid fracturing requirements; analyzing fracture acid erosion data of different reservoirs by using a preset fracture acid erosion calculation model, and analyzing the embedding depth and deformation data of the proppant in combination with the injection rate parameters and the proppant data; further analyzing the sand concentration of sand-acid fracturing, and setting a rough body simulation distribution coefficient in combination with the injection rate, so as to form a reservoir fracture model that presents a real fracturing state; analyzing the permeability state of the reservoir fracture model after fracturing based on the rough body simulation distribution coefficient and the reservoir closure pressure; and further calculating the corresponding conductivity in combination with the fracture width calculated according to the fracture acid erosion data, the embedding depth and deformation data of the proppant. The method solves the problem that the sand-acid fracturing conductivity cannot be quantitatively analyzed, and provides support for field acid fracturing design and productivity prediction.

The invention relates to the technical field of carbon sequestration and geological sequestration, and particularly discloses a slice CO2 water-rock reaction corrosion identification and pore evaluation method based on machine learning, and the method comprises the steps: firstly collecting multi-focal-plane images of the same view field of a slice before and after a reaction on a scanning electron microscope platform, and carrying out the registration; utilizing the trained U-Net instance segmentation model to automatically identify a corrosion area and extract a contour; generating a relative height map through a depth-of-field reconstruction and calibration technology in combination with a multi-focal-plane sequence, and obtaining the effective corrosion depth of each corrosion area; and carrying out volume normalization calculation based on area-depth information, and directly outputting porosity increment and spatial distribution thereof. According to the method, destructive detection is not needed, quantitative volume characterization of corrosion characteristics is achieved, the analysis efficiency and accuracy are remarkably improved, batch processing and mineral phase layering statistics are supported, and reliable data support is provided for CO2 geological storage reaction mechanism research and reservoir simulation.

The invention provides a thick oil saturation degree measurement experiment device and method based on multi-physics field coupling, and belongs to the field of oil and gas field development. The thick oil saturation degree measurement experiment device comprises an oil reservoir simulation system, an oil reservoir development system and a remaining oil content measurement and control system; the three-dimensional sand-packed model wrapping shell is filled with porous medium filler, the interior of the three-dimensional sand-packed model wrapping shell is connected with a formation pressure system through a pipeline, and the exterior of the three-dimensional sand-packed model wrapping shell is connected with a model communication system; the oil reservoir development system comprises an injection supply system, a measurement and control system and a well pattern system. The remaining oil content measurement and control system comprises a pressure guiding detection system, an electric conduction detection system, a heat conduction detection system and a multi-physical field coupling saturation degree measurement system. According to the heavy oil saturation measurement experiment device and method based on multi-physics field coupling, oil saturation quantitative evaluation of the development effect in the heavy oil reservoir development simulation experiment process is met.

The embodiment of the invention relates to the technical field of seismic reservoir prediction, and particularly discloses a seismic reservoir prediction result evaluation method, which comprises the following steps: collecting and integrating historical data of a target seismic reservoir, generating standard acquisition data and a seismic reservoir prediction map, selecting a plurality of verification points, and performing error comparison verification. Geological constraint matching and reservoir simulation analysis are carried out on the seismic reservoir prediction map, and a confidence assessment level is generated and displayed; through collection and integration of historical data, construction of a seismic reservoir prediction map, acquisition of actual drilling data, error comparison verification, geological constraint matching and economic evaluation, comprehensive assessment analysis and generation of a confidence assessment level, a prediction result can be systematically, quantitatively, comprehensively and accurately assessed, and the accuracy of the prediction result is improved. The uncertainty risk of oil-gas exploration decision making is reduced, and the problems of resource waste, low development efficiency and the like are avoided.

The invention discloses a tight oil reservoir depletion type development wave and region evaluation device and method. The device comprises a tight oil reservoir simulation system, a horizontal well system, a pressure monitoring system and a production system, the tight oil reservoir simulation system comprises a reservoir simulation device and a fluid injection device which are connected. The reservoir simulation device can be filled with sand grains in a layered manner so as to simulate a target tight oil reservoir; the fluid injection device is used for injecting simulated formation water and simulated formation oil; the horizontal well system comprises a plurality of horizontal wells; each liquid production pipe is connected with a corresponding horizontal well outlet and is connected with a produced liquid metering device; the pressure monitoring system comprises a signal processor, a pressure sensor and a plurality of pressure probes; and the plurality of pressure probes are arranged in the reservoir simulation device. According to the device, the distribution rule of the sweep area can be identified according to the pressure change, the recovery ratio corresponding to the sweep area can be obtained, and therefore sweep area evaluation is achieved through physical simulation, and production guidance is provided for depletion type development of tight oil reservoirs.

A method may include obtaining grid model data regarding a geological region of interest. The method may further include obtaining well data regarding a well in the geological region of interest. The method may further include obtaining a grid model for the geological region of interest based on the grid model data and the well data. The method may further include obtaining a time selection for a look-ahead simulation. The method may further include determining a look-ahead model for the look-ahead simulation based on the grid model data, the well data, and a coarsening function. The method may further include performing the look-ahead simulation using the look-ahead model and the time selection. The method may further include performing a reservoir simulation of the geological region of interest using the grid model and the look-ahead simulation.