The embodiment of the invention provides a method and device for determining the size and quantity of bubbles in foaming oil. The method comprises the steps that firstly, a first CT scanning image of a first rock core obtained after being dried with wash oil is obtained; a second CT scanning image of a second rock core in the first pressure state is obtained; a third CT scanning image of the second rock core in the second pressure state is obtained; according to the first CT scanning image, the second CT scanning image and the third CT scanning image, the size and quantity of the bubbles in the foaming oil are determined when the pressure in the second rock core is the second preset pressure. By means of the method and device for determining the size and quantity of the bubbles in the foaming oil, the size and quantity of the bubbles in the foaming oil can be more accurately determined.

Method and device for determining size and quantity of bubbles in foaming oil

The invention relates to a method for measuring area changes of CO2-saline water interfaces in a porous medium by using a CT The method comprises the steps of firstly preparing saline water containing potassium iodide to strengthen the image contrast of CO2-saline water; continuously scanning by using the CT to obtain unsteady-state porous medium images under the CO2-saturated condition and different injection conditions; removing a noisy point by using a filter and carrying out threshold processing to generate binary images only containing 0 and 1 of saturated CO2 and under different injection conditions; carrying out subtraction on two image stacks to obtain distribution areas of the saline water in the binary images; extracting the edges of the distribution areas of the CO2 and the saline water and determining a union set to generate binary image slice stacks of the CO2-saline water interfaces; obtaining the area changes of the CO2-saline water interface in the porous medium under different injection conditions through determining and measuring the area of disconnected CO2-saline water interfaces; and calculating the saturability of the saline water in each image slice stack and obtaining area change characteristic parameters of the CO2-saline water interfaces under different injection conditions through induction

Method for measuring area changes of CO2-saline water interfaces in porous medium by using CT

The embodiment of the invention discloses a bubble point pressure value testing method and a bubble point pressure value testing device The method comprises the following steps: drying a porous medium sample and filling a measuring container with the porous medium sample to obtain a first CT scan image of the porous medium sample; injecting crude oil into the measuring container, wherein the pressure value in the measuring container is a first predetermined value, and acquiring a second CT scan image of the porous medium sample; gradually reducing the pressure value in the measuring container till the pressure value of the measuring container is a second predetermined value; acquiring at least one third CT scan image of the porous medium sample in a process of gradually reducing the pressure value; and determining the bubble point pressure value of crude oil in the porous medium sample based on the first CT scan image, the second CT scan image and the at least one third CT scan image The method and device disclosed by the embodiment of the invention can accurately test the bubble point pressure value of crude oil in a porous medium

Bubble point pressure value testing method and device

The invention discloses an acoustic emission detection method for gas-liquid two-phase flow pipeline leakage based on stack self-coding, and belongs to the technical field of pipeline leakage detection The method comprises the following steps of: collecting leakage signals and background noise signals of various flow types of a gas-liquid two-phase flow pipeline, dividing the signals into a training set and a test set, normalizing the training set and the test set by a same maximum value and a same minimum value, adjusting the structure and parameters of a stack self-coding network and usingthe training set for training, using Softmax to classify a result, and verifying the accuracy of a trained model by the test set, so that the trained model can realize the two goals of two-phase flowtype identification and pipeline leakage identification The method can realize accurate identification of the gas-liquid two-phase flow pipeline leakage under complex working conditions, hidden dangers of pipeline leakage can be captured timely, and great help is provided for accident prevention and pipeline maintenance

Acoustic emission detection method for gas-liquid two-phase flow pipeline leakage based on stack self-coding

The invention relates to a device and a method for measuring a Sherwood number between a gas and a liquid in a porous medium by applying CT (Computed Tomography). The device comprises a CT scanning system and a gas-liquid mass transfer system. The method comprises the following steps: first, controlling the temperature and the pressure of a reaction container to be constant; acquiring CT images that the volume of foam in the porous medium changes with time at different liquid injection flow rates and in different liquid injection directions by utilizing a CT scanning imaging technology; obtaining the gas concentration value of the liquid and the value of a two-phase interface specific surface area after the CT images are processed, so that the Sherwood number of mass transfer between the gas and the liquid in the porous medium is calculated. By controlling an experimental device, different liquid injection directions can be set during an experiment process, so that convenience is brought to the analysis of the influence on a gas-liquid interface shape and the Sherwood number numerical value caused by gravity. By applying the method and a measuring device thereof, the Sherwood number between the gas and the liquid under a pore scale can be obtained, so that the cognition of mass transfer rules of the two phase materials of the gas and the liquid is enhanced; basic physical property data are provided for the analysis of multi-phase multi-component migration rules in a stratum environment.

Device and method for measuring Sherwood number between gas and liquid in porous medium by applying CT (Computed Tomography)

The invention relates to a method for calculating an empirical relation expression between gas-liquid Sherwood numbers inside a porous medium by applying CT. The method comprises the steps of firstly calculating the bubble volume content and a gas-liquid mass transfer Sherwood number inside the porous medium of different gas injection and liquid injection directions according to a CT image stack; calculating a liquid-phase Reynolds number according to lamellar average porosity, the bubble volume content and the liquid injection speed; classifying the acquired Sherwood numbers, the Reynolds numbers and the volume content values into different data sets according to different gas injection and liquid injection directions; dividing each data set into a plurality of different local data sets, setting a target empirical relation expression, performing local nonlinear regression analysis, and quickly searching and eliminating abnormal values which are possibly caused by the measurement process by being combined with corresponding CT images; and then performing global nonlinear regression analysis on the remaining data to acquire an empirical relation expression between gas-liquid Sherwood numbers inside the porous medium under different gravity conditions. The calculation and convergence speed of a fitting model is accelerated, a real and effective data result in the experiment process is completely covered, and the model precision is improved.

Method for calculating empirical relation expression between gas-liquid Sherwood numbers inside porous medium by applying CT

The invention belongs to the technical field of multiphase-fluid flow measurement, and relates to a method for calculating a CO2 brine dispersion coefficient by combining CT and PVT The method is used for dynamically measuring an interface change during a CO2-brine mass transfer process, and quantitatively describing a CO2-salt mass transfer change rule under different temperature and pressure conditions CT is applied to acquire a continuous change CO2-brine interface image, two-phase volume and a pressure dynamic change process are observed in real time, a concentration curve is calculatedbased on a CT gray value, and the dispersion coefficient is calculated by combining a Fick law The limitation that an original PVT method cannot directly measure a brine volume dynamic change is broken An error brought by the ignorance of the volume change during a dispersion coefficient calculation process is avoided The shortage of the accuracy in calculating the dispersion system by relyingsolely on a PVT or CT method is recovered A mass transfer theory system is completed

Method for calculating CO2 brine dispersion coefficient by combining CT and PVT

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Device and method for measuring Sherwood number between gas and liquid in porous medium by applying CT (Computed Tomography)

Method for calculating empirical relation expression between gas-liquid Sherwood numbers inside porous medium by applying CT

Method for calculating CO2 brine dispersion coefficient by combining CT and PVT