160 results about "Water flooding" patented technology

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 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 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.

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.

The invention relates to a method and a device for determining an oil reservoir water flooding sweep efficiency. The method comprises the following steps: acquiring a relative permeability curve of an oil reservoir, geological reserves and cumulative oil production and water content at multiple times, and calculating to obtain a water flooding sweep coefficient at the corresponding time according to the relative permeability curve, the geological reserves and the cumulative oil production at the multiple times, obtaining multiple groups of data of the water content and the water flooding sweep efficiency according to the water content at the multiple times and the water flooding sweep efficiency at the corresponding time, and performing nonlinear fitting according to the multiple groups of data of the water content and the water flooding sweep efficiency to obtain a relational expression between the water flooding sweep efficiency and the water content; and according to the relational expression between the water flooding sweep efficiency and the water content, predicting to obtain the water flooding sweep efficiency corresponding to any water content. The relational expression, obtained through the method, of the water flooding sweep efficiency and the water content conforms to the actual development of oil reservoirs, and the change rule between the water content and the water flooding sweep efficiency can be well analyzed.

The invention discloses an ultrasonic enhanced water-oil displacement recovery ratio experiment system based on CT real-time imaging, and belongs to the technical field of oil and gas exploitation experiments. The system is composed of a core clamping and pressure control system, an ultrasonic excitation system, an injection and extraction system, a monitoring and data acquisition system and a data analysis and optimization system. A core holder can accurately simulate underground reservoir pressure and fluid conditions. The ultrasonic excitation system reduces the oil-water interfacial tension through the cavitation effect and micro-vibration, and improves the fluidity and release effect of oil drops; the injection and extraction system is used for accurately controlling the injection flow rate and pressure of displacement liquid to form a stable oil displacement gradient; the monitoring system dynamically captures the core internal oil-water leading edge propulsion, residual oil distribution and ultrasonic cavitation bubble evolution process, and visualization of an ultrasonic energy transfer path under the pore scale is achieved for the first time. The system can effectively research the influence of ultrasonic enhancement on the water drive recovery efficiency, and provides experimental basis and technical support for improving the oilfield development efficiency.

The invention relates to movable shale gas fine gas lift skid-mounted equipment and a control method, the movable shale gas fine gas lift skid-mounted equipment comprises a movable carrier and a flowmeter, a compressor, a plurality of temperature sensors, a pressure sensor, an electromagnetic valve, a frequency converter and a PLC control cabinet which are arranged on the movable carrier, and an inlet of the flowmeter is connected with a natural gas source end; an inlet of the compressor is connected with an outlet of the flowmeter, and an outlet of the compressor is connected with a wellhead gas lift end; the frequency converter is electrically connected with the compressor and is used for adjusting the power of the compressor; the PLC control cabinet is in communication connection with the flow meter, the frequency converter, the temperature sensor, the pressure sensor and the electromagnetic valve. Compared with the prior art, the problems that in the middle and later periods of shale gas well production, the formation pressure is gradually reduced, the yield is reduced, the water carrying capacity of self-spraying production is insufficient, liquid is gradually accumulated in a shaft, and the gas well is flooded to stop production when the liquid is seriously accumulated in the shaft are solved.

The application provides an inorganic gel coagulation inhibitor and a preparation method and application thereof, and the preparation raw material of the inorganic gel coagulation inhibitor comprises acrylamide, temperature-resistant and salt-resistant monomers, cationic monomers and initiators in specific proportions. The acrylamide, temperature-resistant and salt-resistant monomers and cationic monomers are selected and matched, so that the obtained inorganic gel coagulation inhibitor has high steric hindrance effect and cationic group shielding effect, can inhibit the rapid coagulation of silicate and metal cations to form a precipitate, can effectively delay the gelation time of the inorganic gel, and is further applied to water control in the profile control and flooding of high water content oilfields, is helpful to realize the expansion of the swept volume of injected water, improves the water flooding sweep effect, and has a good application prospect.

The invention discloses a method and device for screening oil wells suitable for water plugging in a fault-karst reservoir, and the method comprises the steps: obtaining the water plugging evaluation characteristics of each oil well in the fault-karst reservoir to be evaluated, the water plugging evaluation characteristics including geologic characteristics, fracture-cavity structure characteristics, flooding degree characteristics and oil-water relation characteristics; according to the water plugging evaluation characteristics of each oil well, quantitatively calculating a corresponding water plugging effectiveness potential index; and preferably selecting the oil well with the water plugging potential according to the water plugging effectiveness potential index of each oil well. According to the method, the selection of the oil well suitable for water plugging in the fault-karst oil reservoir is realized, and the accuracy of well selection is improved.

The application discloses a fuel cell water flooding control method, device and storage medium. By constructing a dynamic feature set and calculating a real-time entropy weight score, the water flooding risk state of the anode of the fuel cell can be comprehensively and accurately reflected, and the early warning capability and diagnostic accuracy of the water flooding fault are improved. Based on the real-time entropy weight score, the output power, the loading rate and the drainage flow are dynamically adjusted to realize adaptive control of the water management of the fuel cell, and the hysteresis and excessive regulation problems of the traditional fixed threshold control strategy are avoided. The dependence on artificial experience is reduced, the water flooding risk grade is automatically identified through the data-driven entropy weight analysis method, the water flooding fault probability caused by subjective judgment errors is reduced, the reliability and durability of the fuel cell system are enhanced, and the service life of the fuel cell stack is effectively prolonged.

The invention belongs to the technical field of CO2 geological sequestration experiment evaluation in a CCUS-EOR project, and particularly relates to a carbon dioxide reservoir sequestration effect experiment comprehensive evaluation method. The method comprises the following steps: carrying out a carbon dioxide displacement saturated oil-water rock core experiment, simulating an actual oil reservoir CO2 injection and geological storage process, and calculating a storage evaluation index of CO2 in an experiment simulated oil reservoir on a rock core scale in combination with experimental test data; and quantitatively evaluating the carbon dioxide reservoir storage effect of the target reservoir under the corresponding working conditions by using the core scale CO2 storage index. The technical problem that a CO2 storage experiment method and a storage index quantitative evaluation method for oil reservoirs in the later stage of water flooding development are lacked at present is solved.