15 results about "Reservoir modelling" patented technology

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.

The invention discloses a carbon dioxide geological sequestration simulation device and method, and belongs to the technical field of carbon sequestration simulation. The carbon dioxide geological sequestration simulation device comprises a model box, a simulation reservoir is arranged on the lower layer in the model box, and a simulation cover layer is arranged on the simulation reservoir; the carbon dioxide solution injection module is used for injecting a carbon dioxide solution into the simulated reservoir; the discharged liquid collecting module is used for collecting discharged liquid of the simulated reservoir; the temperature control module is used for controlling the temperature of the model box; the centrifugal module is used for providing gravitational acceleration for the model box; and the data acquisition module is used for detecting and acquiring changes of temperature parameters and pressure parameters of the simulated reservoir and the simulated cover layer. The simulation device provided by the invention simulates the geological storage of carbon dioxide, can observe the change conditions of a carbon dioxide solution in a reservoir and a cover layer under different years, different temperatures and different pressures, and provides support for long-time geological storage of carbon dioxide.

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.

A process of determining a future injection performance of a well, a fluid being intended to be injected from a surface network into a geological formation defining a reservoir, the injection performance providing a relationship between the flowrate and a bottom hole flowing pressure, the process comprising obtaining a first set of data (VLP and bottom hole enthalpy), obtaining a surface network simulator, and a reservoir simulator, providing the reservoir simulator with a current working point of the well, running the reservoir simulator and obtaining updated pressure conditions in the reservoir, calculating a second set of data (IPR) for a next time step, providing the surface network simulator with the second set of data, and obtaining the bottom hole flowing pressure for the next time step and an updated working point. The injection performance is obtained from the second set of data.

This invention belongs to the field of experimental technology for oil and gas field development, specifically relating to an experimental device and method for CO2 injection at the gas-water interface to suppress bottom water displacement of natural gas. The device includes a reservoir simulation system, a fluid injection system, a multi-dimensional visualization monitoring system, and a production metering system. The reservoir simulation system uses a sand-filled pipe to simulate a vertical reservoir, and a temperature control module regulates the temperature of the sand-filled pipe. The fluid injection system uses a fixed-point injection pipe with adjustable depth that can penetrate deep into the pipe body to precisely inject CO2 into the gas-water interface. The multi-dimensional visualization monitoring system uses a scanner and krypton tracers mixed with simulated natural gas and sodium iodide tracers mixed with simulated formation water to achieve dynamic monitoring of multiphase fluids throughout the displacement process. This invention can simulate the vertical development characteristics of deep bottom water gas reservoirs with high fidelity, intuitively revealing the mechanism of CO2 inhibition of bottom water coning, and providing precise experimental basis for optimizing gas reservoir development schemes.

A method comprises measuring a pressure at a plurality of times and a measured flow rate in a well. A measured productivity index (PI) is determined based, at least in part, on the measured flow rate and the pressure at the plurality of times. A flow rate at a second time is simulated, and a fluid pressure at the second time and a third time is simulated. A simulated PI is simulated based, at least in part, on the flow rate at the second time, and the fluid pressure at the second time and at the third time. An updated reservoir simulation model is generated by updating at least one parameter of the reservoir simulation model based, at least in part, on a difference between the measured PI and the simulated PI.

The present application relates to a kind of deep water unconsolidated sediment cap rock sealing capacity determination method, it is related to oil and gas field development technical field, comprising: obtaining the geological data of multiple sample wells in target area, the geological data includes the particle size of reservoir, cap rock at each sample well, mineral composition and the overburden water depth of cap rock;According to the particle size of reservoir, cap rock, mineral composition and overburden water depth, determine the particle size, mineral composition data of simulation reservoir, simulation cap rock in mud sand sealing simulation device and multiple overburden water column height;Carrying out cap rock breakthrough pressure test simulation experiment, obtains the experimental breakthrough pressure of simulation cap rock under each overburden water column height condition;According to experimental breakthrough pressure, calculate the actual breakthrough pressure of cap rock at each sample well;Based on the overburden water depth and actual breakthrough pressure of cap rock at each sample well, build the cap rock sealing capacity model of target area;According to cap rock sealing capacity model, determine the sealing capacity of cap rock at target point in target area.

A method for reservoir simulation is disclosed. The method includes: selecting a coarse grid size for a plurality of grid blocks in a reservoir model of a reservoir (300); calculating, by a computer processor and based on at least water and oil fractional flow curves, a water saturation at a water front within a grid block of the plurality of grid blocks and an average water saturation for the grid block (302, 304); and calculating, by the computer processor and based on at least the water saturation at the water front within the grid block and the average water saturation for the grid block, a water saturation distribution in the reservoir by solving a reservoir simulator equation (308), wherein solving the reservoir simulator equation includes calculating a single water saturation value for each of the plurality of grid blocks based on the coarse grid size.

A method for performing a reservoir simulation includes receiving input data. The method also includes generating one or more subsurface models based upon the input data. The method also includes training a first artificial intelligence (AI) model based upon the one or more subsurface models to produce a first trained AI model. The method also includes training a second AI model by hiding some of the input data to produce a second trained AI model. The method also includes training a third AI model to produce a third trained AI model. The third AI model is trained using simulation performance metrics from simulations performed to train the first AI model and the second AI model. The method also includes performing the reservoir simulation using the first trained AI model, the second trained AI model, and / or the third trained AI model.

The application discloses a chemical reaction hydrocarbon generation heat release steam flooding simulation system and method, wherein the chemical reaction hydrocarbon generation heat release steam flooding simulation system comprises a reservoir simulation device, an injection device, a metering device and a data processing device; the reservoir simulation device is filled with quartz sand as a simulation core, and the simulation core stores crude oil and water; the injection device comprises a steam injection assembly and a reactant injection assembly; the metering device comprises an oil phase metering unit for metering oil production; and the data processing device is used for processing the measurement results of the metering device. Through the system, the needs of reactant substances and injection parameters at different stages of heavy oil development can be determined, thereby providing reliable theoretical guidance for the development of heavy oil reservoirs.

This invention provides a method for constructing a kinetic model of carbon dioxide mineralization and storage reaction considering optimization algorithms, belonging to the field of mining technology. This invention obtains the mineral composition of reservoir cores and constructs a graph database to constrain parameter boundaries. It designs a multi-temperature gradient batch reaction experiment combined with an active learning mechanism to optimize the sampling scheme. A hierarchical optimization strategy is used to gradually invert kinetic parameters from single-mineral to multi-mineral systems. A Gaussian process proxy model is constructed to accelerate the process using coarse and fine grid proxying. The uncertainty of parameters is quantified through Markov chain Monte Carlo sampling. Finally, the laboratory parameters are corrected to the reservoir scale and imported into a reservoir simulator. This invention solves the technical problem of simultaneously ensuring the convergence and identification accuracy of kinetic parameter inversion calculations in multi-mineral coupled systems.

A system and method are provided for identifying a wellsite target for drilling, including receiving a plurality of data regarding a wellsite, generating a distribution of reservoir properties using the plurality of data for an area of a reservoir defined within the wellsite, determining at least one opportunity index for an area in the reservoir based on at least one of the corresponding reservoir properties, classifying a section of the reservoir based on at least one computed embedding space, wherein the at least one computed embedding space of the section is based on the at least one opportunity index.

The invention provides a carbon dioxide mineralization sequestration reaction kinetic model construction method considering an optimization algorithm, and belongs to the technical field of mining industry. Reservoir core mineral composition is obtained, a graph database constraint parameter boundary is constructed, a multi-temperature gradient batch reaction experiment is designed, and an active learning mechanism is combined to optimize a sampling scheme; a layered optimization strategy is adopted to gradually invert kinetic parameters from single mineral to multi-mineral, a Gaussian process proxy model is constructed to realize coarse and fine mesh proxy acceleration, parameter uncertainty is quantified through Markov chain Monte Carlo sampling, lab parameters are finally corrected to a reservoir scale and imported into a reservoir simulator, and a reservoir simulation model is established. The technical problem that convergence and identification precision of mineralization sequestration kinetic parameter inversion calculation under a multi-mineral coupling system are difficult to guarantee at the same time is solved.

The invention relates to the technical field of coal-rock gas multi-layer commingling production of a coal-sand superposed symbiotic composite gas reservoir, in particular to a multi-lithology combined coal-rock multi-layer commingling production physical simulation device. The device consists of five systems, wherein the multi-component gas source simulation system comprises a gas tank which can resist the pressure of 40MPa and is used for providing a stable and controllable gas medium for an experiment; the multi-lithologic reservoir simulation system comprises simulation reservoirs combined by different lithologies (coal rock and sandstone), and DN6 channeling channels are arranged between the reservoirs; the temperature-pressure coupling control system comprises a constant-temperature box with the room temperature of 100 DEG C and a core holder with the confining pressure of 60 MPa; the reservoir dynamic drainage and mining simulation system is used for metering fluid produced in the multi-layer commingling and mining process; and the monitoring and data acquisition system is used for monitoring and recording experimental data. The device can be used for exploring the influence of roofs and baseplates, interlayer fluid channeling, interlayer pressure difference and gas components with different lithologies on coal-rock-gas multi-layer commingling production and adsorption-desorption-diffusion, and provides mechanical knowledge for engineering practice of coal-sand superposed symbiotic composite gas reservoir coal-rock-gas multi-layer commingling production.

This invention provides an integrated wellbore-reservoir simulation device, comprising an integrated wellbore-reservoir functional base plate and a sealing plate fastened to the functional base plate; the functional base plate contains a wellbore simulation cavity and a reservoir simulation cavity located on one side of the wellbore simulation cavity along its length; a through hole connects the wellbore simulation cavity and the reservoir simulation cavity; the reservoir simulation cavity is filled with a medium simulating an oil reservoir. The functional base plate contains both a wellbore simulation cavity and a reservoir simulation cavity to simulate the wellbore structure and the porous medium space of the reservoir. This invention constructs initial reservoir conditions through an injection system and injects water, gas, or steam into the simulation device using a constant flow rate or constant pressure to achieve oil displacement simulation. Combined with a data acquisition system, the fluid migration process and production are observed and measured in real time. This invention achieves coupled simulation of the wellbore and reservoir flow processes, improving the accuracy of the simulation results and their engineering reference value.