82 results about "Reservoir simulation" patented technology

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 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 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 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 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 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 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 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.

Systems and methods include a computer-implemented method for performing well placement and configuration. Two-dimensional (2D) target entry (TE) points are generated in an area of interest (AOI) for wells to be drilled in an oil reservoir, where the 2D TE points are positioned according to a defined well length resolution. A single lateral is designed for each well using the 2D TE points, where each single lateral is designed with a different length, completion zone, azimuth, and orientation. Using the single laterals, a dynamic reservoir simulation is executed for the wells to be drilled in the oil reservoir, including rotating between different three-dimensional (3D) configurations for each 2D TE. A 3D configuration for each 2D TE is selected for each lateral and based on executing the dynamic reservoir simulation.

The invention belongs to the technical field of oil and gas development and exploitation engineering, and particularly relates to an experimental device for heterogeneous reservoir sand water production profile testing and separated bin filling water control effect evaluation and application of the experimental device. The experimental device comprises a gas supply system, a constant-flow liquid supply system, a data measurement and acquisition system, a reservoir simulation unit device, a shaft simulation unit device and a shaft sand water production profile quantitative monitoring device. Wherein the shaft simulation unit device is embedded into the reservoir simulation unit device; the shaft sand water production profile quantitative monitoring device is placed in the shaft simulation unit device. The experimental device can visually simulate the flow law of multiphase fluid (oil / gas / water / sand) according to heterogeneous reservoirs, fractured reservoirs and complex deficit forms, performs heterogeneous reservoir sand water production profile testing and separated bin filling effect evaluation experiments, and provides experimental foundation support for efficient development of oil wells.

The application discloses a kind of mine water recharging multi-field coupling simulation experiment system and method, it is related to mine water utilization technical field.The experimental system includes reservoir simulation box, mine water supply system, production water collection and detection system and microbial culture and injection system;Reservoir simulation box is filled with reservoir medium area, cooperate pressure pump, temperature control jacket simulation deep formation pressure and temperature, mine water supply system provides controllable mine water, microbial culture and injection system injects specific microorganism, and production water collection and detection system detect water quality and microbial characteristics.The experimental method is simulated reservoir condition, injects mine water and microorganism, monitors the change of multiple parameters, establishes composite jamming mathematical model and multi-field coupling partial differential equation.The application can realize stress field, hydrodynamic field and so on five-field coupling simulation, provides technical means for groundwater environment evolution and permeability mechanism research.

The invention relates to a thermal effect-considered numerical simulation analysis method for mechanical integrity of a cover layer of a middle-deep gas storage. Three-dimensional numerical reservoir simulation modeling is carried out by taking a reservoir stratum and a cap stratum as a whole, the reservoir stratum and the cap stratum in the model are divided into two large seepage areas by using a method of setting a seepage barrier, so that gas, oil and water seepage transportation and formation pressure conduction do not occur between the reservoir stratum and the cap stratum, and the reservoir stratum and the cap stratum are subjected to three-dimensional numerical reservoir simulation modeling by setting heat transfer parameters. Cover layer temperature changes caused by cold air injection into the reservoir in the gas storage injection-production process can be achieved, and the influence of the heat effect on the reservoir and cover layer ground stress and mechanical integrity is accurately considered. According to the method, a new index, namely a tension safety index with a normalization characteristic, is adopted, dynamic minimum horizontal principal stresses, obtained through numerical simulation calculation, of different time points in the gas storage injection and production process are combined, the cover layer tension damage risk is accurately and quantitatively evaluated, and the gas storage cover layer mechanical integrity risk is more accurate and conforms to the actual stratum condition.

The invention discloses a simulation system and method of a natural gas hydrate system, electronic equipment and a storage medium. The system comprises a natural gas hydrate system simulation module and a data processing module, wherein the natural gas hydrate system simulation module is used for acquiring hydrate system data corresponding to a target area, establishing a reservoir simulation model corresponding to the target area according to the hydrate system data, and performing simulated gas production simulation based on the reservoir simulation model; and the data processing module is used for collecting simulated gas production data corresponding to the reservoir simulation model in the simulated gas production simulation process and processing the simulated gas production data to obtain a simulation result. Based on the technical scheme, the reservoir simulation model corresponding to the target area is established to simulate the hydrate system of the target area, and the hydrate system of the target area is accurately evaluated according to the simulation data, so that accurate data support can be provided for exploitation of the natural gas hydrate system.

The invention provides a microfluidic microscopic remaining oil form recognition device and method based on a YOLO model, and belongs to the technical field of oil reservoir simulation and analysis, and the method comprises the following steps: S1, data acquisition and preprocessing; s2, feature extraction and coding; s3, boundary constraint and low-rank adaptation fine tuning; s4, decoding and segmentation loss optimization; s5, multi-scale feature fusion and mask refinement are carried out; s6, performing form post-processing and EOR parameter extraction; and S7, performing performance verification and iteration. The YOLO model-based microfluidic microcosmic remaining oil form recognition device and method provided by the invention solve the influence of factors such as fuzzy oil-water interfacial tension, difficulty in micron-sized oil drop trapping and lagging real-time analysis in a dynamic displacement process on the saturation, recovery ratio and multiphase flow relative permeability evaluation of the remaining oil in the prior art.

The present invention discloses a device and method for evaluating the performance of drilling fluid for plugging leaks in marine hydrate reservoirs. The device includes a hydrate reservoir simulation unit, a drilling fluid injection unit, and a leakage metering unit. The drilling fluid injection unit and the leakage metering unit are respectively connected to the hydrate reservoir simulation unit. The drilling fluid injection unit injects plugging drilling fluid into the hydrate reservoir simulation unit, and the leakage metering unit provides drilling fluid leakage measurement for the hydrate reservoir simulation unit. The device also includes a temperature control unit for providing temperature control for the entire device and a control system for data acquisition and control of the entire device. The hydrate reservoir simulation unit, drilling fluid injection unit, leakage metering unit, and temperature control unit are all electrically connected to the control system. The present invention can realize experimental simulation of the performance evaluation of drilling fluid for plugging leaks in marine hydrate reservoirs.

The application discloses a testing device and method for element sulfur solubility in high-sulfur gas reservoir development process, and the testing device comprises a fluid injection system, a reservoir simulation system, a sulfur solubility metering system and a data tracking and processing system; the fluid injection system is connected with the reservoir simulation system; the reservoir simulation system is connected with the sulfur solubility metering system; the data tracking and processing system is connected with the sulfur solubility metering system; the fluid injection system is used for injecting a sulfur-containing gas sample into the reservoir simulation system and the sulfur solubility metering system; the reservoir simulation system is used for simulating the flow of the sulfur-containing gas sample in a reservoir and a complex interface physicochemical action process; the sulfur solubility metering system is used for metering the sulfur solubility in the sulfur-containing gas sample; and the data tracking and processing system is used for processing data. The testing device in the application comprises two sulfur solubility testing units, so that the testing precision is effectively improved, and the measurement loss and safety risk caused by the flow of the sulfur-containing gas sample in pipelines and valves are reduced.

The invention relates to the technical field of teaching tests, in particular to a small pumped storage experimental platform which comprises a water storage tank, a supporting platform is arranged behind the water storage tank, a height-adjustable upper reservoir simulation cabin is arranged on the front side of the top end of the water storage tank, and a height-adjustable hydraulic turbine set is arranged on the rear side of the top end of the water storage tank. The lower reservoir simulation cabin is fixedly installed on the front side of the top end of the supporting platform, the mixing chamber is installed at the top end of the lower reservoir simulation cabin, a water flow adjusting mechanism is arranged between the lower reservoir simulation cabin and the mixing chamber, and the upper reservoir simulation cabin is connected with the hydraulic turbine set through a first communicating pipe. And the hydraulic turbine set is connected with the lower reservoir simulation cabin through a second communicating pipe. Through a height-adjustable simulation system, accurate concentration control, efficient material recycling and an intelligent filtering and cleaning mechanism, a closed-loop experiment environment is constructed; and the authenticity and the data reliability of flood working condition simulation of the pumped storage power station are effectively improved.

This invention provides an optimization method for CO2 injection and production in multi-stage fractured horizontal wells. The optimization method includes: Step S1: Establishing a reservoir simulation calculation model required for CO2 injection and production optimization in multi-stage fractured horizontal wells; Step S2: Establishing the optimization objectives, variables, and constraints for CO2 injection and production in multi-stage fractured horizontal wells; Step S3: Establishing a framework for the optimization method of CO2 injection and production in multi-stage fractured horizontal wells based on PPO; Step S4: Applying the obtained optimization parameters for CO2 injection and production in multi-stage fractured horizontal wells to specific blocks and analyzing the reasons for the high total net present value of the injection and production optimization scheme. This method can simultaneously and dynamically optimize the injection and production rates and durations at different stages of injection and production, achieving variable injection and production rates and durations, which better meets the practical needs of injection and production in mining operations.

Reservoir simulation is performed by constructing an embedded discrete fracture model (EDFM) having matrix grid cells (180a) and extra continuum grid cells in the simulation grid. The EDFM is integrated into a multi-porosity-multi-permeability (MPMP) framework of a parallel reservoir simulator. Each fracture polygon of the fractures (181c) in the reservoir is divided into a set of fracture cells for calculating matrix-fracture connections (183b) and fracture-fracture connections (183b), which are all neighbor connections between grid cells that are face or edge neighbors. These neighbor connections may be intra-continuum connections or inter-continua connections that are stored in the matrix grid cells (180a) and / or fracture grid cells in the integrated EDFM / MPMP framework. The reservoir simulation is performed by the parallel reservoir simulator based on the cell connectivity data in the integrated EDFM / MPMP framework to facilitate well production of the reservoir.

A method for generating history matched grid data. The method includes obtaining observed production data and obtaining latent grid data. The method further includes processing the observed production data to form observed latent production data and generating denoised latent grid data by removing noise from the latent grid data using a diffusion model guided by the observed latent production data and a time encoding. The method further includes generating history matched grid data by decoding the denoised latent grid data and optimizing production of a well using the history matched grid data.

The embodiment of the application provides a kind of based on agent model's oil reservoir remaining oil prediction method and system, the method includes: setting oil reservoir simulation data, combining oil reservoir simulation module, generate sample data set;Based on the data type of sample data set, corresponding data preprocessing is carried out, and data is converted into two-dimensional matrix form;Residual oil prediction model is constructed, and residual oil prediction model is the encoder-decoder network of fusion residual structure, and coordinate attention mechanism is introduced;Two-dimensional matrix form sample data set is input data, and residual oil prediction model is iteratively optimized, and iteration is until convergence, to obtain the trained residual oil prediction model;The complete input parameter of target oil reservoir is acquired, and the trained residual oil prediction model of input complete parameter is output target oil reservoir remaining oil distribution result.

The application discloses a geological fault simulation device and method, relates to the technical field of geological simulation, and comprises a supporting seat, a simulation concave disc, plate block fault simulation blocks, a reservoir simulation hose and a cover plate. The simulation concave disc is rotatably installed on the supporting seat, the plate block fault simulation blocks are assembled inside the opening side of the simulation concave disc and are provided with two, the reservoir simulation hose is installed in the plate block fault simulation blocks and is adjustable in shape, and the cover plate is arranged on the opening side of the simulation concave disc. The sliding assembly, the adjusting assembly and the sealing mechanism are arranged, the simulation process can be finely adjusted by the adjusting assembly, the plate block fault simulation blocks can be highly sealed by the sealing mechanism, the plate block fault simulation blocks can be highly flexibly adjusted by the sliding assembly and the adjusting assembly, the fine adjustment can be realized in the fault simulation process, and the combination of high sealing performance and high flexible adjustment performance can be simultaneously satisfied.

The application relates to the field of oil and gas geophysical prospecting engineering and discloses a method for effectively monitoring carbon dioxide storage leakage, which comprises the following steps: S1. establishing a geological model for carbon dioxide storage and performing reservoir simulation, and constructing a time-lapse synthetic model with different carbon dioxide saturations; S2. using rock physics theory, analyzing reservoir rock physics response characteristics under different carbon dioxide saturations, and deducing an elastic parameter model; S3. using a viscous-sound wave equation of a standard linear solid attenuation model to carry out seismic forward simulation, generating time-lapse seismic data, and performing reverse-time migration imaging; and S4. based on the reverse-time migration profile obtained in S3, using a frequency spectrum ratio method of an imaging domain to perform real-time monitoring on leakage conditions of carbon dioxide in early, middle and late stages after injection. The workflow provided by the application realizes comprehensive monitoring and prediction on carbon dioxide plume migration by integrating reservoir simulation, rock physics analysis and time-lapse seismic monitoring technology.