Abstract: The present invention provides a device and a method for measuring fluid saturation in nuclear magnetic resonance (NMR) on-line displacement, the method comprising: measuring a nuclear magnetic resonance (NMR) T2 spectrum under the dead volume filling of the on-line displacement system as displacing phase fluid and the core to be measured as saturated nuclear magnetic detection phase fluid to generate a calibrated T2 spectrum; measuring a nuclear magnetic resonance (NMR) T2 spectrum of a process in which the core to be measured is converted from a saturated displaced phase fluid into a displacing phase fluid to generate a displacement process T2 spectrum; generating the fluid saturation of the on-line displacement system in real time according to the generated calibrated T2 spectrum and the displacement process T2 spectrum. The present invention achieves the purpose of improving measurement precision of fluid saturation in the on-line displacement process.

Abstract: The present invention relates to a method and system for quantitatively evaluating surface roughness of an organic pore of kerogen in shale. The method includes: making a shale sample; applying a circle of silver-painted conductive tape on the edge of the shale sample to obtain a processed sample; conducting image scanning on the processed sample to obtain a scanned image; determining a kerogen area according to the scanned image; determining an organic pore area according to the kerogen area; carrying out gridding treatment on the organic pore area to obtain multiple grid cells; adopting double integral calculation on each of the grid cells to obtain the areas of the multiple grid cells; summing each of the areas to obtain the surface area of the organic pore; and evaluating surface roughness of the organic pore according to the surface area of the pore.

Abstract: The present disclosure provides a method for quantitative evaluation on a sensitivity of a shale oil and gas reservoir to injected fluids. The method includes the following steps: (I) preparation of rock samples; (II) quantitative evaluation on sensitivities of a shale porosity and a bedding fracture permeability to an injected fluid; and (III) quantitative evaluation on a sensitivity of a shale matrix permeability to an injected fluid. A method for comprehensive evaluation on a sensitivity of a shale oil and gas reservoir to injected fluids is innovatively provided based on the nuclear magnetic resonance testing technology with two basic physical property parameters: porosity and permeability. The method realizes quantitative evaluation on sensitivities of pores of different sizes and matrix of shale and a bedding fracture permeability to injected fluids, and realizes quantitative and accurate evaluation on a sensitivity of a shale oil and gas reservoir to injected fluids.

Abstract: A system is provided for detecting the mass of oil in an inorganic mineral of shale. The system operates by performing an extraction test on a first shale sample by using chloroform to obtain a total content of shale oil in the shale; enriching kerogen from the second shale sample to obtain dry kerogen; and performing an extraction test on oven-dried kerogen by using chloroform to determine the mass of extracted kerogen. The system also operates by determining the mass of the oil in the organic matter of the shale sample and the mass of the oil in an inorganic mineral of the shale; establishing a model for predicting a ratio of the mass of the oil in the inorganic mineral of the shale to the mass of the oil in the organic matter; and using the prediction model to determine the mass of oil in an inorganic mineral.

Abstract: The present disclosure provides a high-pressure helium shale porosity testing device and method. The device comprises a reference cylinder, a pressure cylinder, a sample cylinder, a differential pressure sensor, a pressure gauge, an venting and vacuumizing system, a temperature control system and a tubing and valve system, wherein the reference cylinder is respectively connected with a helium source, the pressure cylinder and the sample cylinder through the tubing and valve system, the differential pressure sensor is configured to measure changes of pressure difference between the sample cylinder and the pressure cylinder, the pressure gauge is configured to measure pressure at the pressure cylinder, the sample cylinder is further connected with the venting and vacuumizing system through the tubing and valve system, and the temperature control system is used for controlling the temperature of the whole device.

Abstract: The invention relates to a composite shock absorber for a polycrystalline diamond compact bit, comprising a drilling tool body having a water inlet, an impact body having a water outlet and forming a shock absorption cavity, a disc spring group having an annular pressing sleeve, a cylindrical torsion bar spring which has an external thread and a spline, is connected to the drilling tool body through threads and extended into an impactor and connected thereto through the spline, and the annular pressing sleeve, wherein bit vibration impact force is transmitted therebetween through a torsion transmission joint, and a bearing group is arranged between the lower end surface of the annular pressing sleeve and an annular step of the impact body. The composite shock absorber can weaken damage of the slippage effect to polycrystalline diamond compact cutting teeth, absorb axial vibration from a drill stem and prolong the service life of the bit.

Abstract: A leakage detection method for a long petroleum pipeline based on AFPSO-K-means includes: initializing a particle swarm, and defining an initial velocity and an initial position of each particle in the particle swarm; determining a fitness value of the each particle; traversing the fitness value of the each particle to obtain an optimal position corresponding to the fitness value of the each particle and a global optimal position in optimal fitness values of the particle swarm; iteratively updating a velocity and a position of the each particle based on the optimal position corresponding to the fitness value of the each particle; and when a distance from the position of the each particle to the global optimal position is less than a preset threshold or a number of iterations reaches a preset value, outputting a current iteration updated result to determine an actual leakage position of the petroleum pipeline.

Abstract: A method for identifying mineral pore types in mud shale includes: determining an inorganic mineral pore image and a kerogen region image of a mud shale Scanning Electron Microscopy (SEM) gray-scale image; performing an expansion operation on the inorganic mineral pore image to obtain an expanded inorganic mineral pore image; comparing the inorganic mineral pore image with the expanded inorganic mineral pore image, and determining an extra region in the expanded inorganic mineral pore image as an expansion region; collecting statistics about the number of pixel points of a siliceous mineral, a calcareous mineral, and a clay mineral; calculating the proportion of each mineral according to the number of pixel points of the minerals; drawing a mineral pore triangular image chart according to the proportions of minerals; and determining the mineral type corresponding to the pores in the inorganic mineral pore image according to the mineral pore triangular image chart.

Abstract: The present invention relates to a method and system for quantitatively evaluating surface roughness of an organic pore of kerogen in shale. The method includes: making a shale sample; applying a circle of silver-painted conductive tape on the edge of the shale sample to obtain a processed sample; conducting image scanning on the processed sample to obtain a scanned image; determining a kerogen area according to the scanned image; determining an organic pore area according to the kerogen area; carrying out gridding treatment on the organic pore area to obtain multiple grid cells; adopting double integral calculation on each of the grid cells to obtain the areas of the multiple grid cells; summing each of the areas to obtain the surface area of the organic pore; and evaluating surface roughness of the organic pore according to the surface area of the pore.

Abstract: Method for preparing high-strength and durable super-hydrophobic film layer on inner wall of elongated metal tube includes roughening treatment of inner wall of a metal tube, electrodepositing preparation of nickel-phosphorus alloy layer and functional coating, heat treatment, subsequent anodizing and low surface energy modification. The method greatly reduces the influence of local mass transfer resistance, and a uniform nanocrystalline film layer is electroplated under the ultrasound induction. Since only electroplating solution is filled in the tube during the preparation process, the consumption of device and raw materials is greatly reduced. Also, since silica particles are added to the electroplating solution in preparing the nanocrystalline film layer, the surface morphology can be made more uniform and denser in terms of the microscopic morphology.

Abstract: A long-acting super-hydrophobic coating resistant to water pressure impact and preparation method thereof. The long-acting super-hydrophobic coating includes a conductive substrate and the following raw materials in parts by weight: 1 part to 10 parts of titanium source or zinc source, 40 parts to 100 parts of deionized water, 20 parts to 50 parts of hydrochloric acid or 20 parts to 40 parts of sodium hydroxide, 1 part to 10 parts of electrolyte, 1 part to 10 parts of low surface energy modifier, 10 parts to 20 parts of high molecular polymer, 1 part to 5 parts of carbon nanotube and 70 parts to 100 parts of organic solvent. The long-acting super-hydrophobic coating has an organic-inorganic nano-interpenetrating network structure, which improves the stability of the multi-stage nano-micro structure, so that the super-hydrophobic coating surface has a good high-pressure water impact resistance and high-pressure static water resistance.

Abstract: A leakage detection method for a long petroleum pipeline based on AFPSO-K-means includes: initializing a particle swarm, and defining an initial velocity and an initial position of each particle in the particle swarm; determining a fitness value of the each particle; traversing the fitness value of the each particle to obtain an optimal position corresponding to the fitness value of the each particle and a global optimal position in optimal fitness values of the particle swarm; iteratively updating a velocity and a position of the each particle based on the optimal position corresponding to the fitness value of the each particle; and when a distance from the position of the each particle to the global optimal position is less than a preset threshold or a number of iterations reaches a preset value, outputting a current iteration updated result to determine an actual leakage position of the petroleum pipeline.