The invention relates to a three-dimensional large scale physical model of a fracture-cave type carbonate reservoir and a preparation method of the three-dimensional large scale physical model. The model is composed of a simulated karst cave, a simulated fracture and a constant temperature oven. The preparation method specifically includes the steps that a carbonate rock outcrop which is tested and analyzed is sealed through a reaction still to simulate the karst cave, and a fracture is simulated through pipeline filling to press carbonate grains; valves and joints are used for connecting the sealed simulated karst caves and the simulated fractures which are in different number and different space positions, so that a simulated carbonate fracture-cave network structure is formed and mounted in the constant temperature oven, and the three-dimensional large scale physical model of fracture-cave type carbonate rocks is formed. According to the three-dimensional large scale physical model of the fracture-cave type carbonate reservoir and the preparation method of the three-dimensional large scale physical model, not only a complex space network structure between actual reservoir stratums of fracture-cave type carbonate oil and gas reservoirs can be simulated, but also the physical and chemical properties of solid phase reservoir rocks can be reflected, high temperature and high pressure conditions of the actual reservoir stratums can be simulated, and production effects when wells are drilled at different positions can be simulated.

Three-dimensional large scale physical model of fracture-cave type carbonate reservoir and preparation method of three-dimensional large scale physical model

The invention discloses a physical model test device and method for determining a flowback time of gas well fracturing and quantity of reflux of propping agent fracturing fluid. The physical model test device for determining the flowback time of the gas well fracturing and the quantity of reflux of the propping agent fracturing fluid comprises a cylindrical body, a first end cover, a second end cover, a pressurizing device, a gas injecting device, and a reflux device and pressure test probes; the cylindrical body is provided with an internal cavity for placing a core, a liquid inlet and an in-and out opening which are located at both ends and separately communicate with the internal cavity, and a reflux opening, test holes and a pressurizing hole which are arranged at side portions and separately communicate with the internal cavity; the first end cover and the second end cover are separately and correspondingly arranged at the liquid inlet and the in-and-out opening, and the first endcover, and the second end cover and the inner wall of the inner cavity are enclosed together to form a closed and build-the-pressure cavity body; and the pressurizing device passes through the pressurizing hole and is used for connecting with the core in a butting mode and pressurizing the core, and providing a closed pressure for a fractured core to fixing the core.

Physical model test device and method for determining flowback time of gas well fracturing and quantity of reflux of propping agent fracturing fluid

The invention discloses a method for improving the oil displacement effect of a strong vertical heterogeneous oil reservoir. The method comprises the steps that a high-permeable core and a low-permeable core which are of different permeability ratios are separately selected; experimental simulation formation water is prepared; experimental simulation oil is prepared; the cores are saturated with the Mn simulation formation water, the porosity is measured, and the pore volume is calculated; the high-permeable core and the low-permeable core are connected in parallel, oil displacement of the cores is simulated through an experiment, and magnetic resonance imaging T2 spectra are measured; the simulation formation water and CO2 are sequentially used, a surfactant is injected, the CO2 is reused, the simulation formation water is injected at a certain speed after the CO2 is injected, foam liquid is injected after the CO2 is injected, the magnetic resonance imaging T2 spectra are measured, and oil displacement efficiency is calculated; and oil displacement efficiency in different displacement modes is added to obtain the total oil displacement efficiency of the high-permeable core and the low-permeable core. By adoption of the method, a large hole channel of a high-permeable oil reservoir can be sealed, oil-water interfacial tension of a low-permeable oil reservoir is reduced, the oil displacement effect of the low-displacement oil reservoir is improved, and therefore the overall oil displacement effect of the strong vertical heterogeneous oil reservoir is effectively improved.

Method for improving oil displacement effect of strong vertical heterogeneous oil reservoir

A device for determining an injected water optimal mineralization degree of a limestone oil reservoir comprises a measurement module and an analysis module. The measurement module comprises a high-pressure power pump, an injected water sample storage container, a rock core clamp, an annular pressure pump, an oil-water separator, a back-pressure valve, a back-pressure power pump and a constant-temperature tank. Two ends of the rock core clamp are provided with a first pressure sensor and a second pressure sensor respectively, and data signal output ends of the first pressure sensor and the second pressure sensor are connected with the analysis module. A method for determining the injected water optimal mineralization degree of the limestone oil reservoir includes: preparing series of watersamples in different mineralization degrees; measuring a stable displacement differential pressure, and calculating core oil recovery rate of the series of injected water samples in different mineralization degrees; drawing a curve of the injected water mineralization degree, the oil recovery rate and the stable displacement differential pressure; determining an optimal injected water mineralization degree parameter of a target oil reservoir. Therefore, optimal selection of injected water for target limestone oil reservoir water injection measures is guided.

Device and method for determining injected water optimal mineralization degree of limestone oil reservoir

The invention discloses a method for testing visualized propping fracture flow conductivity, and belongs to the technical field of hydraulic fracturing. The method comprises the following steps: firstly, testing fracture width and closing pressure of a proppant under different sanding concentrations; then, using the fracture width as an objective function and adopting multiple linear regression toobtain a relational expression of the fracture width, the sanding concentration and the closing pressure; then, using a visualized proppant transporting device to perform a proppant conveying experiment; recording the total weight of a proppant during the experiment; calculating the total area of a proppant laying form at the end of the experiment; obtaining a visualized experimental sanding concentration; then, substituting the obtained visualized experimental sanding concentration into the relational expression of the step two; obtaining the corresponding fracture width according to the required closing pressure; and then adjusting the fracture width of the visualized proppant transporting device to the corresponding fracture width. The method provided by the invention solves a problemthat a transparent panel of the visualized proppant transporting device is unable to withstand high pressure by adopting a method of adjusting the fracture width instead of applying the closing pressure after the closing pressure is equivalent to the fracture width.

Method for testing visualized propping fracture flow conductivity

The invention discloses a simulation and evaluation system for a low-salinity water injection experiment and method. The method comprises the following steps: (1) preparing displacement liquids in different salinities, performing a displacement experiment by using a specific serial core holding unit, determining the natures of effluent from each core corresponding to the displacement liquids in different salinities at different moments in real time, and determining a yield-increasing effect of each displacement liquid; (2) evaluating the change conditions of the clay transferring, wettability reversal, double electrode layer diffusion, ion exchange, mineral dissolution and pH value before and after the water flooding, and supplying basis to the evaluation for a yield-increasing mechanism; and (3) combining low-salinity water injection with other tertiary oil recovery methods for evaluating the yield-increasing effect and the yield-increasing mechanism. The method disclosed by the invention has the beneficial effects that (1) the reaction between three phases of oil, water and rock in the displacement experiment can be evaluated in real time; (2) the yield-increasing effect of the combination of low-salinity water injection with other tertiary oil recovery methods can be evaluated, and the joint yield-increasing mechanism can be evaluated; (3) and the theoretical basis can be supplied to the injection liquid preparation scheme in practical operation.

Simulation and evaluation system for low-salinity water injection experiment and method

The invention relates to an experimental device and method for simulating single-crack flowback after shale gas fracturing The experimental device is mainly composed of a pump set, a device body, a hydraulic pressure and temperature control device, and a tail monitoring and liquid waste disposal device The device body mainly refers to an improved rock core clamp holder specially used for manufacturing a rock core, confining pressure is applied through the hydraulic pressure device, and the temperature control device heats hydraulic oil to form a high temperature for simulation of the stratum environment; in the experimental process, displacement meters on the upper side face and the lower side face of the rock core clamp holder can detect crack displacement change, and the sand production rate and the fluid flow speed can be monitored in real time through the tail monitoring device By the adoption of the experimental device and method, the stratum high-temperature and high-pressure environment can be simulated, and on the premise that the flow conductivity of cracks of different crack lengths and crack widths is detected, the crack pressure drop, the sand production rate, the propping agent embedding degree and the propping agent backflow and settlement rule are detected; moreover, artificial marble rock cores are used, and the environment gets more close to the true stratum environment compared with the mode that steel blocks are used for simulating cracks

Experimental device and method for simulating single-crack flowback after shale gas fracturing

The invention discloses a method for processing experimental data of dynamic capillary effect evaluation experiments of an oil reservoir, and the method comprises the following steps: (1) arrangement of basic parameters; (2) determination of rock core average water saturation and average oil saturation; (3) determination of dynamic capillary force, to be more specific, in-situ dynamic capillary force detected at each point is corrected, the geometric center of a rock core, an oil phase and a water phase is determined, essence phase average oil phase pressure and water phase pressure are calculated, and the dynamic capillary forceis determine; and (4) determination of oil phase and water phase dynamic relative permeability, to be more specific, effective water saturation is calculated, center water saturation point with water saturation of Sp in capillary pressure curve is taken, the capillary pressure corresponding to the water saturation Sp is P, logarithmic coordinate slope (F) of the point is calculated, parameter m can be obtained by Genuchten model fitting, and water phase dynamic relative permeability (Krw) and oil phase dynamic relative permeability (Kro) can be calculated respectively.

Method for processing experimental data of dynamic capillary effect evaluation experiments of oil reservoir

The invention relates to a device and a method for measuring the porosity and the grain breakage rate of compressed piled sand. The device mainly adopts a theory of communicating vessels and micro-compressibility of water and comprises a hydraulic device, a sealing rubber base block, a compression base block, an internal metal mold, an internal transparent observation window, an external glass measuring tool, bottom communicating micro-channels and the like; fine sand as a proppant is added to the internal metal mold, then water is added to the mold until the piled sand is just submerged in the water, the piled sand is compressed through the compression base block, the water subjected to compression flows into the external glass measuring tool through the bottom communicating micro-channels, and the increased water yield, namely, the reduction degree of the porosity of the piled sand can be read. The device and the method have the beneficial effects as follows: the porosity change and the grain breakage rate of the compressed piled sand as well as the proppant embedding degree can be measured, and support is provided for optimization of a proppant laying manner and prediction of the relation of sand packed crack width with pressure change; the device is simple in structure, light and easy to operate.

Device and method for measuring porosity and grain breakage rate of compressed piled sand

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Papers

Simulation and evaluation system for low-salinity water injection experiment and method

Experimental device and method for simulating single-crack flowback after shale gas fracturing

Method for processing experimental data of dynamic capillary effect evaluation experiments of oil reservoir

Device and method for measuring porosity and grain breakage rate of compressed piled sand