206 results about "Water flooding" patented technology

The invention relates to the technical field of reservoir numerical simulation, and discloses a polymer flooding reservoir rapid simulation optimization method considering sedimentary facies constraints, which comprises the following steps: identifying sedimentary facies boundaries according to distribution characteristics of sedimentary facies, and establishing a connected network model considering the sedimentary facies constraints on the basis of the sedimentary facies boundaries, well positions and various sedimentary facies attributes; carrying out one-dimensional grid division on the connected network model, converting the connected network model into a grid connection format of a universal simulator, and solving the connected network model by adopting the universal simulator to obtain pressure and saturation solutions; establishing an automatic historical fitting mathematical model based on sedimentary facies and oil reservoir constraint conditions; the economic net present value is used as an index, the water injection rate, the liquid production rate and the polymer injection rate of each well are used as optimization variables, the differential evolution algorithm is used, the total polymer injection amount and the oil reservoir pressure are restrained, and an oil reservoir injection and production optimization mathematical model is established. According to the method, the oil reservoir is optimized by comprehensively considering the characteristics of the oil reservoir after water flooding is converted into polymer flooding, so that rapid decision-making of the oil field and guidance of oil field construction are realized.

The invention relates to the field of oil and gas exploration and development displacement testing, provides a preparation and experiment method of a visual large-size planar heterogeneous core, and provides a large-size planar heterogeneous model with a specific structure, and the preparation method comprises the steps of raw material preparation, pressure forming, temperature control curing, cementing sealing, pouring, curing demolding and the like. The prepared rock core is used for simulating oil displacement experiments including water flooding, chemical flooding and subsequent water flooding so as to observe the sweep effect and the plugging effect of a chemical additive in the rock core, the performance of the chemical additive is evaluated in combination with actual production requirements of an oil reservoir, and theoretical guidance is provided for field practice.

Provided are a method for evaluating reservoir scaling during water flooding, and an application and device thereof. The method comprises: acquiring the ion concentration, cumulative distribution of solid phase particle size counts, and core permeability before displacement; acquiring the multipoint pressure and core permeability of a core, cumulative distribution of solid phase particle size counts, and ion concentration during and / or after the displacement; acquiring ion concentration change, the minimum retained particle size within the core, scaling location, and the degree of core damage; completing evaluation of reservoir scaling during water flooding.

The invention discloses a residual oil quantitative evaluation method and device, a medium and computing equipment. The method comprises the steps that a ship bottom type remaining oil distribution mode of the homogeneous thin layer bottom water reservoir is determined; obtaining the strong water flooding radius under various bottom water thicknesses in the double-high development stage; obtaining quantitative expressions of remaining oil enrichment areas under various bottom water thicknesses; and obtaining the weak water flooding thickness H of each position of the oil reservoir. The residual oil quantitative evaluation method comprises the following steps: establishing a standard model under different bottom water thicknesses by acquiring strong water flooding radiuses under various bottom water thicknesses in a double-high development stage, and determining a classified bottom water reservoir mixed source displacement mode; aiming at the difficulty in shaping and quantitative description of'ship bottom type 'residual oil, positioning of a potential enrichment area is carried out based on water logging interpretation of a passing well, and rapid quantitative expression of the residual potential area is realized by acquiring quantitative expressions of the residual oil enrichment area under various bottom water thicknesses, so that a reliable basis is provided for accurate potential tapping of residual oil in a double-high stage; and the process is simple and efficient.

The invention discloses an oil reservoir polymer flooding process oil-water distribution simulation method and device based on a cellular automaton, equipment, a medium and a product, and relates to the field of oil reservoir engineering and seepage mechanics. The method comprises the steps that rectangular grid division is conducted on an oil reservoir space, three-dimensional coordinates of cellular nodes are determined, and a cellular automaton model is constructed; according to the polymer oil displacement scheme parameters, oil reservoir state parameters at the end moment of water displacement are initialized, and boundary conditions of the mole-type cellular automaton model are established; making an evolution rule for each neighborhood cellular node in the Moire cellular automaton model; according to a numerical value stability rule, adjusting parameters of each neighborhood cellular node in the Mohr-type cellular automaton model; according to the method, a relative permeability nonlinear regulation and control rule is formulated for the Mohr-type cellular automaton model to simulate oil-water distribution in the oil reservoir polymer flooding process of the Mohr-type cellular automaton model, the starting pressure gradient is accurately simulated, and the low-permeability oil reservoir evolution process is accurately described.

The invention discloses a fuel cell water and gas discharge control method, device and equipment and a readable storage medium, and the method comprises the steps: presetting a first calibration quantity and a second calibration quantity of periods and opening durations of a water discharge valve and a gas discharge valve, and enabling the second calibration quantity to have a shorter period and a longer water and gas discharge duration; when it is monitored that the idle running time of the fuel cell system exceeds the first threshold value, the control parameters of the drain valve and the exhaust valve are switched from the first calibration quantity to the second calibration quantity, and the control parameters are switched back to the first calibration quantity after the set time is continued, so that the working condition that the circulating gas flow is reduced under long-time idle running is adapted; liquid water and accumulated gas in the galvanic pile are effectively discharged by adjusting the period and duration of drainage and exhaust; the problems of liquid water gathering, circulating flow attenuation, local water logging of the electric pile, local film drying, unbalanced gas concentration and the like caused by traditional fixed parameter control during long-time idling operation can be avoided, the voltage consistency of the electric pile is guaranteed, and the fault that the voltage of a single piece is too low is reduced.

The invention discloses a molecular dynamics simulation method for CO2-ion oil displacement, and belongs to the technical field of CO2 oil displacement. The method comprises the steps that an oil molecule model, a water molecule model, a CO2 molecule model, a CaCl2 molecule model and a graphene plate model corresponding to target oil reservoir characteristics are established; carrying out geometric structure optimization on each model; the optimized molecular model is assembled into a 'CO2-CaCl2-H2O' ternary displacement system, and molecular dynamics simulation is executed; during simulation, an NVT ensemble is selected, periodic boundary conditions are applied, a COMPASS II force field is adopted, atomic potential parameters are configured, and after operation energy is minimized and temperature is initialized, displacement process simulation is executed; and quantitatively evaluating the oil displacement effect of the displacement medium of the 'CO2-CaCl2-H2O' ternary system on the basis of the trajectory file output by simulation. According to the method, the behavior of molecules under the synergistic effect of multiple displacement media can be better explained, the oil displacement micromechanism under the synergistic effect of the multiple displacement media is embodied, and the method has important significance for optimizing the compact oil reservoir development effect and improving the recovery efficiency.

The invention relates to the technical field of oil and gas field development, and provides an oil field reinjection sewage pollution radius and plug removal effect evaluation method which comprises the following steps: S1, preparing a rock core and forming a plurality of injection holes, S2, testing the water permeability before pollution by clear water flooding, S3, testing the water permeability and resistance coefficient of each area after pollution by sewage flooding to evaluate the pollution degree, and S4, carrying out plug removal by a plug removal agent. And S5, sequentially testing the water permeability and the residual resistance coefficient of each region after blockage removal by clear water drive region by region and section to obtain the pollution blockage removal effect of each region, and making an evaluation, so as to simulate the blockage flow-back process of the wellhead after the blockage removal of the oil field. The method can be used for evaluating the pollution degree of the reinjection well and the effect of the blockage removal measure, guiding the site to take related measures in time, and reducing the problem of water injection capacity reduction caused by pollution, so that the service life of the reinjection well is prolonged, and the oilfield development benefit is improved.

The present invention relates to a method for predicting the breakthrough time of water drive in carbonate oil reservoirs based on an agent model, comprising the following steps: S1: selecting and disclosing a data set of actual production history of a certain oil reservoir; S2: dividing the natural water drive of the oil reservoir into four types of water drive according to the production dynamics of the oil reservoir; S3: using a finite element conceptual model to simulate and calculate the relevant parameters of the oil reservoir to obtain a numerical simulation sample data set; S4: constructing four types of water drive breakthrough time prediction sub-models; S5: constructing a training set of four types of water drive breakthrough time prediction sub-models; S6: training each type of water drive breakthrough time prediction sub-model to finally obtain a trained prediction model; S7: correcting the trained prediction model to obtain a final carbonate oil reservoir water drive breakthrough time prediction model. The use of this technical solution can solve the shortcomings of the existing methods for predicting the breakthrough time of water drive in oil reservoirs, such as long time consumption, poor adaptability and pertinence, and can effectively guide the specific development work of actual oil wells.

The invention belongs to the technical field of oil exploitation, and particularly relates to a nano bubble generator, a nano bubble preparation method and a method for improving recovery efficiency by using nano bubbles, the nano bubble generator comprises a bubble generator main body, a containing cup and at least one bubble water filter plate, the mesh apertures of the adjacent bubble water filter plates are different, and the containing cup is arranged in the containing cup. The mesh diameter of the bubble water filter plate close to the water inlet end is larger than that of the bubble water filter plate close to the water outlet end. According to the bubble water filter plate disclosed by the invention, nano bubble water is converted into the nano bubble water through an extrusion shearing effect and is extruded out of the meshes, large bubble water can be converted into the nano bubble water, and the gas mixing uniformity is good; by using the nano-bubble method, the injection pressure during water flooding is effectively improved, the swept volume is enlarged, the flowing direction of oil and water is microscopically regulated and controlled, the oil washing efficiency is improved, and residual oil which is difficult to extract by conventional water flooding is effectively displaced.

The invention provides a method for determining a nanofluid oil displacement effect of a low-permeability reservoir, and relates to the technical field of oil exploitation. The method comprises the following steps: providing a core of a low-permeability reservoir, and measuring the particle size of nanoparticles in a target nanofluid; performing high-pressure mercury injection test and nuclear magnetic resonance measurement on the rock core to respectively obtain a rock core pore throat radius-distribution frequency relation curve and a first T2 image, and performing benchmarking on the two images to obtain a pore throat radius-relaxation time relation curve; carrying out displacement experiments (oil displacement, first water displacement, nanofluid displacement and second water displacement) on the rock core, and carrying out nuclear magnetic resonance measurement to obtain T2 images; and observing or calculating the area enclosed by the curve and the relaxation time in each image, and combining with a pore throat radius-relaxation time relation curve to obtain the oil displacement effect of the nanofluid on different pores of the oil reservoir. The oil displacement effect of the nanometer system is determined according to the characteristic parameters of the reservoir core before and after the nanometer fluid is injected, and the method has important guiding significance for formulating a scheme for improving the recovery effect of the low-permeability oil reservoir.

The embodiment of the invention provides a riverside and lakeside zone remote sensing monitoring method and product. The riverside and lakeside zone remote sensing monitoring method comprises the following steps: acquiring historical medium-resolution remote sensing image data and historical high-resolution remote sensing image data; extracting an end member spectrum of a typical ground feature from the historical medium-resolution remote sensing image data; correcting the end member spectrum according to the high-resolution remote sensing image data and eliminating shadow or cloud interference to obtain a target end member spectrum matrix; performing pixel unmixing on the to-be-decomposed medium-resolution remote sensing image data according to the target end member spectrum matrix to obtain a pixel unmixing result; determining a water level amplitude variation area according to the pixel unmixing result and the flooding frequency; determining a coastal zone monitoring range according to the water level amplitude variation area; inputting image data corresponding to the monitoring range of the coastal zone into a wavelet transform U-Net deep convolutional neural network model to obtain a land utilization classification result of the coastal zone; and quantifying the ecological bank zone ratio result of each river reach according to the land utilization classification result of the coastal zone.

The invention discloses a method, a system, equipment and a medium for detecting an oil-water two-phase relative permeability curve, and belongs to the technical field of oil-gas field development technologies. The detection method of the oil-water two-phase relative permeability curve comprises the following steps: washing oil and drying a rock core sample, vacuumizing the rock core sample, and injecting formation water into the rock core sample, so that the rock core sample reaches a saturated water state; injecting crude oil into the core sample at a preset oil reservoir temperature to enable the core sample to reach a saturated oil state; performing water-displacing oil operation on the rock core sample at a preset flow rate, and scanning the rock core sample at a plurality of scanning nodes by using a CT (Computed Tomography) scanning device; oil saturation and water saturation are calculated according to an actually measured rock core CT value, and parameter fitting is performed on the Corey model according to the oil saturation and the water saturation to obtain an oil-water two-phase relative permeability curve. The method can accurately detect the oil-water two-phase relative permeability curve of the rock core.

The invention discloses an oil reservoir oil displacement simulation experiment device and method based on a stratum complex structure, and belongs to the technical field of oil reservoir development, the device comprises a stratum simulation box body, a compaction module is arranged at the top of the stratum simulation box body, a movable sand filling module is arranged between the stratum simulation box body and the compaction module, and a detachable simulation oil displacement shaft is arranged in the box body. The method comprises the following steps: preparing simulated stratum sand grains; selecting a producing well and surrounding water injection well positions and installing a shaft; sand grains are filled layer by layer through the sand filling module, and the retention time is adjusted according to the stratum thickness; selecting a sand layer as a simulated oil layer, injecting simulated oil, standing, continuously filling sand, and drilling and sealing at the corresponding height of the shaft; the sand filling module is removed, a compaction plate is installed, a corresponding check block of a shaft is taken down, and heating is conducted while hydraulic compaction is conducted; a producing well shaft is opened for sealed oil production, and the recovery ratio is calculated; opening a shaft of the water injection well to seal and inject water to displace remaining oil, and performing secondary extraction and analyzing the water flooding effect. The technical problem of seepage rule simulation distortion of an existing oil reservoir oil displacement simulation experiment device is solved.

The application provides a device and method for simulating low-efficiency water drive thick oil viscosity reduction composite drive enhanced oil recovery, which comprises an injection system, a three-dimensional large-size sand filling model, a multi-well back pressure measurement and control system and a multi-well flow metering system. The injection system is connected to the three-dimensional large-size sand filling model, and fluid is injected into the three-dimensional large-size sand filling model which can simulate well pattern mode. The multi-well back pressure measurement and control system is connected to the three-dimensional large-size sand filling model, and the formation pressure is set. The multi-well flow metering system is connected to the three-dimensional large-size sand filling model, and the output fluid is metered. The device and method for simulating low-efficiency water drive thick oil viscosity reduction composite drive enhanced oil recovery can meet the enhanced oil recovery experiments of water drive, polymer drive, viscosity reduction drive, viscosity reduction composite drive and the like of three-dimensional large-scale heterogeneous reservoir models under different well pattern modes, and has important significance for the enhanced oil recovery of low-efficiency water drive thick oil reservoirs.

The invention discloses a follow-up water drive potential tapping method based on flow field comprehensive analysis, and belongs to the technical field of potential tapping of remaining oil in a high-water-content stage in the middle and later periods of oilfield development. The method comprises the following steps: quantitatively identifying a dominant seepage channel based on streamline distribution, an oil saturation field and a water passing multiple of a target oil reservoir; dividing six remaining oil types and determining distribution characteristics of the remaining oil types; pressure system research and reasonable injection-production ratio regulation and control are combined, and differential potential tapping countermeasures for different remaining oil types are provided. According to the method, the development problems of high water content and low recovery degree in the subsequent water flooding stage of polymer flooding are effectively solved, and the oil reservoir recovery efficiency and development benefits can be remarkably improved.

The invention relates to the field of oilfield chemistry, in particular to an amphiphilic block poly-surfactant containing a surfactant functional group and a preparation method of the amphiphilic block poly-surfactant. Through molecular structure design, a self-made amphiphilic block copolymer macromonomer is added, a side chain of the macromonomer has a hydrophobic polycaprolactone block and a hydrophilic polyethylene glycol block at the same time, and the side chain with the built-in amphiphilic block integrates strong emulsification stripping and hydrophobic association effects at the same time; due to the strong emulsifying and stripping capacity to residual oil after water flooding and the deep profile control capacity to a reservoir, the recovery efficiency of an oil reservoir after water flooding is remarkably improved.

This invention discloses a method utilizing nuclear magnetic resonance double-T E The method for classifying water flooding levels in well logging is as follows: First, the transverse relaxation rate of nuclear magnetic resonance (NMR), the geometric mean of the mobile fluid portion of the T2 spectrum, and the double T2 spectrum are calculated sequentially using NMR logging data. E The geometric mean difference of the mobile fluid portion of the T2 spectrum was measured. Then, the porosity of different components was obtained by inversion of echo data under long waiting times and short echo intervals. Finally, the percentage content of macroporous components in the total porosity was plotted against the T2 spectrum. E Cross plot of geometric mean difference of the mobile fluid portion of T2 spectrum and plotting of array induced resistivity AT90 and double T E The cross plot of the geometric mean difference of the mobile fluid portion of the T2 spectrum is measured to identify the flooding level of the flooded layer: unflooded layer, low flooded layer, medium flooded layer, and high flooded layer.

The application provides a Pickering emulsified solvent profile control agent and a preparation method and application thereof. The Pickering emulsified solvent profile control agent comprises the following raw material components in percentage by mass: 1.0%-3.0% of nano-bentonite particles, 0.005%-0.05% of a surface modifier, 0.0005%-0.001% of a pH regulator, 5%-20% of solvent oil, and the balance of water. The Pickering emulsified solvent profile control agent has high viscosity, strong flow control and good stability. When applied to water flooding of thick oil cold production, the Pickering emulsified solvent profile control agent can effectively reduce the viscosity of thick oil, has high sweep efficiency, and can effectively improve the recovery rate of water flooding of thick oil cold production.

The application provides a method for realizing high-multiple water flooding core microcosmic residual oil dynamic characterization, which comprises the following steps: reconstructing digital images of pore space distribution and two-phase fluid distribution by using image processing method according to core microcosmic distribution images at different displacement moments obtained in the displacement process; taking the pore space at the initial displacement moment as a benchmark, calculating the local size of the pore structure, determining the critical cross section of different pore regions according to the derivative of the maximum local region of the core pore size change, and dividing the core microcosmic structure into pore regions; and statistically analyzing the dynamic change characteristics of the core microcosmic properties and fluid distribution at different displacement moments in the divided local pore regions, so as to realize the core microcosmic displacement dynamic characterization. The pore region division method provided by the application can decompose the complex core microcosmic pore structure into multiple pore regions, and can directly quantitatively characterize the dynamic response of the displacement core microcosmic properties and internal fluid characteristics from the local structure.

1. The name of this design product: Water injection and water flooding monitoring transmitter (JSZJ‑30T intelligent array electromagnetic method). 2. The purpose of this product design: It is used for water injection monitoring during oil and gas development, monitoring the migration of oil and water, clarifying the effective direction of water drive, delineating the water drive front, and evaluating the water drive effect, so as to guide the optimization and adjustment of the water injection process. 3. The design key point of this appearance design product lies in the shape. 4. The picture or photo that best illustrates the design points: Stereoscopic diagram 1.

The invention discloses a carbonate reservoir multi-scale process simulation method and device. The device comprises a jacketed simulation cylinder, a slide, a sapphire negative plate, a sapphire cover plate, a pressure chamber and a clamping device, a mounting groove, and an injection groove I, an injection groove II, an injection groove III and an extraction groove which are communicated with the mounting groove are formed in the sapphire substrate; the slide is mounted in the mounting groove; fluid capsules are respectively placed in the injection groove I, the injection groove II and the injection groove III; the jacket type simulation cylinder is provided with a temperature control cavity and a pressure cavity; the sapphire cover plate covers the sapphire bottom plate, and the sapphire cover plate and the sapphire bottom plate are mounted in the clamping device together; and the clamping device is mounted in the pressure chamber. The invention mainly aims at solving the problems of micromodel manufacturing and microcosmic devices in the process of researching the water-oil displacement and chemical agent oil displacement rules of the carbonate reservoir from a microcosmic angle indoors, and providing technical support for researching the water-oil displacement and chemical agent oil displacement mechanisms of the carbonate reservoir indoors.

The invention discloses a quantitative prediction method for water logging of a well section of an infilled horizontal well of an offshore water-drive oil field. The method comprises the following steps: S1, dividing a well spacing area of the horizontal well into a plurality of grids; s2, establishing a displacement pressure, gravity and buoyancy coupled flooding thickness quantitative prediction mathematical model, and drawing a waterline propulsion chart; s3, based on the waterline propelling condition, the remaining oil distribution coefficient of the well spacing area is calculated; s4, screening remaining oil gathering grids according to the remaining oil distribution coefficient, and quantitatively judging the water logging condition of the well section of the horizontal well; and S5, reevaluating the enrichment degree of the remaining oil, and further evaluating and determining the potential tapping grid of the horizontal well. According to the quantitative prediction method for flooding of the well section of the infilled horizontal well in the offshore water-drive oil field, three-dimensional representation of the flooding position and the flooding degree of the well section of the infilled horizontal well in a high-water-content oil reservoir can be achieved, the remaining oil enrichment area suitable for implementing the horizontal well can be accurately screened and evaluated, then well position deployment of the horizontal well is guided, and the infilled adjustment effect is improved.

The invention relates to a method for observing and quantitatively analyzing microscopic displacement of water-displacing oil, and belongs to the technical field of oilfield development. The method specifically comprises the following steps: preparing a core sample into a visual rock slice assembly; injecting fluid into the visual rock slice assembly to carry out a displacement experiment, recording a video of the distribution condition of the fluid in the slice, intercepting a picture, and establishing fluorescent picture standard samples of the rock slice in different states; oil-bearing areas before and after displacement are analyzed from the pictures; and analyzing the occurrence state of the residual oil. The defects that a glass etching model cannot reflect a real core pore structure and the definition of a recorded displacement video or picture is low are overcome.

The application provides a rock creep model construction method and system based on cyclic water flooding-stress coupling, and relates to the technical field of rock mechanics and engineering.The initial physical and mechanical properties of a rock sample are tested through a permeation experiment and a stress permeability experiment to obtain water permeability and stress permeability, a covariance matrix of characteristic parameters is obtained by using principal component analysis, the principal components related to water permeability and stress permeability are screened out, rock fracture sensitivity coefficients and stress sensitivity coefficients are calculated, a water migration equation is constructed based on Darcy's law, and is coupled with the sensitivity coefficients to form a rock creep relationship and construct a rock creep prediction model, clustering analysis is performed by using historical data to obtain clustering intervals of different risk levels, and the risk level of the rock creep prediction value is determined.The application realizes accurate prediction of the creep behavior of rocks in a complex environment by coupling water permeability and stress permeability.

The invention discloses a fuel cell response test method, which is characterized by comprising the following steps of: carrying out rapid variable load test: simulating 0-100% rated power step change, and recording voltage oscillation, local hot spots and water logging phenomena; a start-stop cycle test: high-frequency on-off of hydrogen / air supply is carried out, and the oxidation-reduction attenuation characteristic of the catalyst is evaluated; and transient disturbance test: superposing current fluctuation of random frequency, and analyzing the dynamic evolution rule of the pile impedance spectrum. The invention has the following advantages: 1, a gas supply rapid following mode is provided; 2, a high-precision dew point controllable technology is provided; and 3, a high-precision simulation actual road condition load mode is provided.

The application discloses a coal mine underground water flooding simulation method, which comprises the following steps: step 1, collecting roadway coordinates and floor elevations obtained by underground measurement, and representing underground connected roadways as a collection of multiple roadway sections; step 2, setting a water outlet position of water flooding simulation, determining a roadway section where the water outlet position is located, and determining a corresponding roadway section name, a starting point coordinate and a tail point coordinate; step 3, projecting a roadway model to obtain a water flow direction and a waterlogging position of water flooding simulation; and step 4, rotating a coordinate axis of the XZ or YZ plane roadway model in step 3 to obtain a ZX or ZY plane roadway model, calculating waterlogging volume by using the ZX or ZY plane roadway model in the rotated two-dimensional coordinate system, and simulating water flooding height. The application realizes quantitative water flooding simulation, and compared with an existing simulation water flooding model, the application realizes a data-driven model, and is more interpretable and universal.

The invention relates to the technical field of hydropower station safety, and discloses a hydropower station underground powerhouse flooding fault rapid simulation prediction method, which comprises the following steps: S1, constructing a rapid simulation analysis model, a parameter system of the rapid simulation analysis model comprising geometric parameters, hydraulic parameters and disaster parameters; s2, dividing a hydropower station underground powerhouse space of the rapid simulation analysis model into a plurality of reservoirs, and establishing a water balance equation; s3, the drainage capacity of a drainage system of the rapid simulation analysis model is calculated; s4, establishing a water leakage risk point leakage model of the rapid simulation analysis model, and calculating water inlet flow; and S5, based on the mass conservation equation and the momentum conservation equation, simulating the whole process from initial leakage to complete submerging by adopting a time stepping algorithm, and outputting a prediction simulation result. The method accurately simulates and predicts the flow and water level elevation penetrating into the plant according to the spatial structure characteristics of the underground plant, so as to improve the emergency decision accuracy and response speed.

The invention discloses a core displacement process physical property change analysis method and system, and the method comprises the following steps: obtaining initial core images before and after displacement; segmenting pores, clay and particles in the initial rock core image to obtain target rock core images before and after displacement; and multiplying the target rock core images before and after displacement to obtain a multiplied intersection result graph, and carrying out microscopic quantitative analysis on the physical property change in the rock core displacement process. According to the method, the three phases of pores, particles and clay in the rock core image are segmented and multiplied to obtain the multiplied intersection result graph, and the mutual change condition of the three phases of pores, particles and clay is directly observed and analyzed from a microscopic view angle through the multiplied intersection result graph; furthermore, a stratum matrix skeleton change micromechanism in the aspects of particle migration and clay particle hydration expansion caused by the fluid scouring effect in the oil reservoir displacement process is analyzed, and the method has profound significance in improving the water flooding development effect.

The application provides an oil layer water flooding degree evaluation method and device based on two-dimensional gas chromatography information. O , D w and D three technical parameters can obtain the water flooding degree of the oil layer, reduces the technical parameters for evaluating the water flooding degree of the oil layer, the evaluation process is simple, the cost is low, the accuracy is high, and the defects of the traditional water flooding layer logging evaluation method, such as technical complexity, high cost and poor accuracy, are overcome.