264 results about "Reservoir type" patented technology

A system for identifying a reservoir used with a fluid delivery device. The system includes a reservoir comprising a housing for holding fluid and a colored marking located on a surface of the housing. A fluid delivery device includes a compartment for receiving and operatively coupling with the reservoir. A light source shines light on the colored marking of the reservoir. A color sensor detects wavelengths reflected and / or refracted from the colored marking due to the light shined on the colored marking. A processor of the delivery device determines a color of the colored marking from the detected wavelengths and ascertains information related to the reservoir or the fluid in the reservoir corresponding to the determined color, wherein the processor operates the fluid delivery device according to the ascertained information, wherein the information may include a reservoir type and / or medication type.

The object of the present invention is to minimize the risks of dose dumping associated with the concomitant consumption of alcohol and certain modified-release pharmaceutical or dietetic forms. The invention relates to an oral form comprising microparticles of the reservoir type for the modified release of at least one active principle (AP), characterized in that it is resistant to immediate dumping of the dose of AP in the presence of alcohol. In particular, the oral form according to the invention is characterized in that the time taken to release 50% of the AP in an alcoholic solution is not reduced more than 3-fold relative to the time taken to release 50% of the AP in an alcohol-free aqueous medium. The form comprises an agent D, which is a pharmaceutically acceptable compound whose hydration or solvation rate or capacity is greater in an alcohol-free aqueous medium than in alcoholic solution

The invention relates to an Archie mode method for determining oil layer initial oil saturation, comprising the following steps: (1) inspecting the structure of oil pool and the geological condition of a reservoir bed, and collecting relevant sampling data; (2) correcting initial oil saturation and initial water saturation data; (3) calculating the average value of the initial oil saturation or the initial water saturation according to a downhole single sand layer, namely, a substratum; (4) calculating the average value of average degree of porosity according to the single sand layer, namely, the substratum, and reading the corresponding stratum deep direction-finding resistivity data by well logging curve; (5) collecting the data and drawing; (6) establishing the Archie mode of different reservoir bed types for a single layer with approximate reservoir bed deposition and oil pool and reservoir formation characteristics; and (7) calculating the initial oil saturation for the unsampled oil layer requiring the calculation of the initial oil saturation by using the Archie saturation formula. The initial oil saturation calculated by applying the method has high precision.

The present invention discloses a method and an apparatus for predicting performance profiles of multi-layered oil reservoirs, wherein the method comprises: dividing the multi-layered oil reservoirs into a plurality of blocks, and determining a reservoir type, formation factor Kh and an evaluated reserves of each layer in each block; selecting a block representing geologic features of the multi-layered oil reservoirs from the plurality of blocks as a representative block, to build a fine geological model of the representative block; building corresponding fine numerical simulation model according to the fine geological model of the representative block, and determining type curves of different reservoir types under different development strategies; determining a relation curve between Kh and well injection rate for injectors and a relation curve between Kh and well production rate for producers in the multi-layered oil reservoirs under different restrictive conditions; predicting performance of the multi-layered oil reservoirs according to the type curve, the relation curve between Kh and well injection rate, the relation curve between Kh and well production rate, and the reservoir type, formation factor Kh and evaluated reserves of each layer in each block.

A system for identifying a reservoir used with a fluid delivery device. The system includes a reservoir comprising a housing for holding fluid and a colored marking located on a surface of the housing. A fluid delivery device includes a compartment for receiving and operatively coupling with the reservoir. A light source shines light on the colored marking of the reservoir. A color sensor detects wavelengths reflected and / or refracted from the colored marking due to the light shined on the colored marking. A processor of the delivery device determines a color of the colored marking from the detected wavelengths and ascertains information related to the reservoir or the fluid in the reservoir corresponding to the determined color, wherein the processor operates the fluid delivery device according to the ascertained information, wherein the information may include a reservoir type and / or medication type.

The pharmaceutical preparation for transdermal administration contains solvent ingredients, such as water and ethanol and / or propanol, and drospirenone. The drospirenone is contained in the preparation in an amount that is not above its saturation solubility in an initial state prior to application to skin. However after application to the skin the amount of drospirenone exceeds its saturation solubility due to escape or discharge of the solvent ingredients from the preparation. Preferably the saturation solubility is exceeded by at least a factor of five during application to the skin. The pharmaceutical preparation can also contain an estrogen, such as ethinyl estradiol. It can be in the form of a semi-solid or liquid preparation that is contained in a reservoir-type transdermal patch. A transdermal patch for contraception containing the pharmaceutical preparation including drospirenone and ethinyl estradiol is also disclosed.

The present invention relates to a coffee maker and more specifically to a two cups automatic coffee maker with flow control in a precise manner, particular to a one cup coffee in desired volume, a two reservoirs type design to avoid overfill and able to have two different tastes, with a manual reset thermostat controls to turn off the heaters while brewing cycle is completed.

A system for identifying a reservoir used with a fluid delivery device. The system includes a reservoir comprising a housing for holding fluid and a colored marking located on a surface of the housing. A fluid delivery device includes a compartment for receiving and operatively coupling with the reservoir. A light source shines light on the colored marking of the reservoir. A color sensor detects wavelengths reflected and / or refracted from the colored marking due to the light shined on the colored marking. A processor of the delivery device determines a color of the colored marking from the detected wavelengths and ascertains information related to the reservoir or the fluid in the reservoir corresponding to the determined color, wherein the processor operates the fluid delivery device according to the ascertained information, wherein the information may include a reservoir type and / or medication type.

A real-time formation fluid logging multi-parameter hydrocarbon reservoir comprehensive interpretation and evaluation method comprises the following steps that each logging parameter is manually collected and recorded through a comprehensive logging instrument and a real-time formation fluid logging instrument; the obtained logging interpretation and evaluation parameters are optimized and classified to form a logging interpretation database; reservoir division is interpreted; an interpretation and evaluation standard is selected and interpretation and evaluation feature parameters are optimized according to area geological features, the reservoir types and logging interpretation parameters; the interpretation and evaluation standard and the interpretation and evaluation feature parameters are substituted into a comprehensive interpretation and evaluation model. The real-time formation fluid logging multi-parameter hydrocarbon reservoir comprehensive interpretation and evaluation method improves the logging oil gas comprehensive interpretation agreement rate, and can quantify the evaluation indexes and ranges.

The present invention discloses a multi-layer oil reservoir overall yield prediction method. The method comprises: dividing a multi-layer oil reservoir into a plurality of blocks, determining a reservoir stratum type, a formation factor Kh and an evaluated reserve volume of each small layer of each block; selecting, from the plurality of blocks, a block representing a multi-layer oil reservoir geological feature as a representative block, establishing a fine geological model of the representative block; establishing a corresponding fine numerical simulation model according to the fine geological model of the representative block, determining a typical mining curve of different types of reservoir strata in different development manners; determining a relationship curve between a single well injection amount and Kh in the multi-layer oil reservoir, and a relationship curve between a produced quantity and Kh; and predicting a multi-layer oil reservoir yield according to the typical mining curve, the relationship curve between the injection amount and Kh, the relationship curve between the produced quantity and Kh, and the reservoir stratum type, Kh and evaluation reserve volume of each small layer of each block. According to the multi-layer oil reservoir overall yield prediction method, the prediction accuracy of the multi-layer oil reservoir overall yield is improved, and further, working efficiency is improved.

The invention discloses a method for identifying a fluid type of a reservoir with a complicated pore structure by using conventional logging information and relates to the technical field of judgment of the fluid type according to logging information for oil-gas field exploration and development. The method comprises the steps of 1, distinguishing a gas layer from a non-gas layer according to a ratio of the neutron porosity to the acoustic porosity or the density porosity, wherein the non-gas layer comprises a dry layer, a gas-water layer and a water layer; 2, distinguishing an effective reservoir from an ineffective reservoir in the non-gas layer by a pore-full intersection method; and 3, based on the effective reservoir in the second step, comprehensively identifying the fluid type of the reservoir by a pore-power intersection method and gas logging. According to the method disclosed by the invention, the technical problem in evaluation of fluid type identification for a high-porosity dry layer, a middle-porosity dry layer, a high-resistance water layer and a high-resistance gas-water layer well which have high bound water characteristics under the condition that only conventional logging information is provided is effectively solved, and the difficulty in judgment of the reservoir type represented by the Majiagou formation is effectively solved.

The invention discloses a production-increasing method by water-plugging and fracture, comprising the following steps: mixing 5 to 7 proportions of crack shielding agents with 100 proportions of clean water; injecting a mixture a into pressed cracks of a well layer under the temperature of 0 to 45 DEG C; shielding an aperture in a storage layer; mixing 5 to 10 proportions of bottom water oil reservoir plugging agent with 100 proportions of low-viscosity fracturing fluid; injecting the mixture generated in step c into cracks pressed in oil layer or gas layer under the temperature of 0 to 45 DEG C; plugging lower water layer after deposition of the mixture; carrying out sand-adding and fracturing operation on the oil layer or the gas layer at the upper part of the storage layer; closing a well and waiting for condensation then fishing the construction. In the method, the bottom water oil reservoir type or the bottom water gas reservoir type gas well bottom is plugged, the jumping-up of bottom water is prevented, simultaneously the crack height is controlled effectively, the extending-down of the crack is prevented, therefore, the aims of plugging the water layer is achieved and the single-well output of an oil well or a gas well is improved.

The invention provides a high permeability band characterization method based on time varying. The method includes the steps that according to petroleum reservoir development dynamic and dynamic monitoring of high permeability band performance characteristics, high permeability bands in a mine field are recognized; screening and quantification of dynamic and static parameters for high permeability band characterization are performed; standardization and weight of the dynamic and static parameters are determined; the high permeability bands are comprehensively distinguished in a multi-index mode, summation is performed according to the product of standardized values and weight parameters of the dynamic and static parameters, and comprehensive discriminant values are obtained; the high permeability bands are classified, the development strength of the high permeability bands is recognized according to the mine field, and the comprehensive discriminant values are partitioned into intervals to serve as high permeability band classification standards. The high permeability band characterization method based on time varying can achieve quantitative characterization of the longitudinal and planar positions of the high permeability strip bands by synthesizing various influence factors of the high permeability strip bands, needed parameters can be obtained easily, the method is easy and convenient to operate, and reliable geological bases can be provided for strong heterogeneity governing of the reservoir type.

The invention provides three-dimensional artificial rainfall reservoir type landslide physical model testing equipment. The equipment comprises a box body, wherein the periphery and the bottom of the box body are sealed, the top of the box body is provided with an artificial rainfall system; a landslide bed is arranged in the box body; a landslide body is arranged on the landslide bed; the top end of the landslide bed is provided with a rear edge water complementing system for simulating ground water flow; a physical quantity test and control system is arranged in the landslide body; a TDR water testing system is arranged on one surface of the landslide body; a reservoir water level control system for controlling the water level in right front of the landslide body is arranged outside the box body; an exit gate is also arranged on the box body in right front of the landslide body. The testing platform system has the high integration and automation degrees, can be used for deformation damage model tests of a landslide under the action of a plurality of factors, and can perform the three-dimensional landslide physical simulation test research on landslide stability characteristic with the consideration of rainfall, reservoir water level rising and falling and coupling functions.

The invention relates to a log multi-parameter oil-gas layer interpretation and evaluation method based on a radar map and a cloud model. The method comprises the steps of: obtaining interpretation and evaluation parameters by normal geological log, gas log, geochemical log, nuclear magnetic log and the like; integrating log interpretation databases; drawing the log multi-parameter oil-gas interpretation radar map according to different reservoir types in different areas by using the databases; and mapping the interpretation parameters onto the rays of the radar map. The radar map is divided into a good reservoir, a medium reservoir and a poor reservoir from inside to outside; the area of the radar map is taken as the characteristic quantity for finishing characteristic extraction; the area of the radar map is used to calculate a cloud boundary equation, and the cloud boundary equation is mapped on the manufactured cloud scale; the cloud model is the same as the radar map, namely the reservoir is divided into a dry layer area, a low-yield oil-gas layer area and an oil-gas layer area with industrial value from inside to outside. The intuitional and quantitative interpretation and evaluation of log multi-parameter oil-gas reservoirs is realized by the radar map and the cloud model. The interpretation coincidence rate can be increased, and the interpretation conclusion is represented by a graph, so that the log multi-parameter oil-gas layer interpretation and evaluation method is intuitional in expression and strong in applicability.

The invention belongs to the technical field of evaluation for gas storages of gas fields, and particularly relates to an evaluating method for a closure property of a lithologic gas reservoir type gas storage. The evaluating method comprises the steps that evaluation of the closure property of a cover plate and a bottom plate is performed, specifically, the macroscopic closure property of the cover plate and the bottom plate is evaluated firstly, and then the microscopic closure property of the cover plate and the bottom plate is evaluated; the evaluation of the closure property of a lateralboundary is performed, specifically, the microscopic closure property of the lateral boundary is evaluated firstly, then a spatial form of the lateral boundary is evaluated, and finally dynamic evaluation of the lateral boundary is performed; and the overall sealing capability of the gas storage is inspected. According to the evaluating method for the closure property of the lithologic gas reservoir type gas storage, the problem that no systematic evaluating method for the sealing capability of the lithologic gas reservoir type gas storage is obtained in the prior art is solved; and the evaluating method is scientific, reliable, and highly operable on site, the sealing property of the gas storage is more accurately judged, the problem that the closure property of the lithologic gas reservoir type gas storage is difficult to demonstrate due to the trapped boundary is solved, the construction risk and the operational risk of the gas storage are reduced, and the safety of the gas storageis improved.

The invention belongs to the technical field of slope stability diction and slope disaster monitoring and precaution, and particularly relates to a method for detecting a displacement and reservoir water level coupling power prediction parameter and stability of a reservoir type slope geological disaster. According to the basic principle of damage mechanics, a skid resistance force and sliding force loading power parameter on the slope sliding face and a slope displacement response parameter are organically coupled, and the new method for determining the stability of the reservoir type slope is disclosed according to the organic coupling. The method can effectively overcome erroneous judgment or misjudgment caused by errors of slope physical and mechanics parameters, boundary conditions and the like in a traditional ultimate equilibrium mechanical evaluation method and meanwhile solves the problems that a traditional displacement time sequence prediction method cannot describe a slope power action mechanism in a quantitative mode and cannot stably unify instability criterion. The clear criterion is adopted to specifically express the stability state of the slope in different stages of the reservoir, and effective basis is provided for slope prediction forecast and precaution treatment.

The invention discloses a sweet spot identification and comprehensive evaluation method for a tight sand reservoir. According to the method, eight conventional logging curve data are taken as a basis. By utilizing the SPSS data analysis software, common factors capable of comprehensively reflecting the characteristics of a reservoir in a target area are extracted based on the PCA (principal component analysis) method. According to the physical significance of each common factor, the sweet spots of the tight sand reservoir are recognized, and a sweet spot qualitative recognition model for the tight sand reservoir is established. On the above basis, a common factor calculation model for porosity and permeability is established in conjunction with physical property test data, so that the types of the reservoir are divided. According to the physical property parameters of various reservoir types and the parameter characteristics of common factors, a quantitative evaluation standard for the tight sand reservoir is determined. Therefore, the qualitative recognition and the quantitative evaluation for the sweet spots of the tight sand reservoir are realized. Based on the method, a novel idea and a novel method are provided for the interpretation and evaluation of the tight sand reservoir. Therefore, the interpretation and evaluation reliability of the tight sand reservoir is improved. The exploration and development cost is reduced.

The invention discloses a four-quadrant reservoir stratum type identification method and system, wherein the four-quadrant reservoir stratum type identification method comprises the following steps: selecting a core sample, and acquiring the mud filtrate specific resistance and electrical imaging logging information of a well corresponding to the core sample; performing CT scanning imaging on the core sample to generate a CT imaging pore distribution spectrum of the core sample; according to the mud filtrate specific resistance and the imaging logging pixel conductivity, computing an electrical imaging porosity spectrum of the well corresponding to the core sample by utilizing the Archie's formulas; calibrating the electrical imaging porosity spectrum corresponding to a stratum segment by utilizing the CT imaging pore distribution spectrum, and computing the mean value and distribution variance of the calibrated electrical imaging porosity spectrum; performing standardized treatment on the mean value and distribution variance of the calibrated electrical imaging porosity spectrum to generate the standard mean value and distribution variance of porosities; forming a two-dimension plane by the standard mean value and distribution variance of porosities, wherein the standard mean value of porosities is the abscissa axis, and the standard distribution variance of porosities is the ordinate axis; and identifying the reservoir stratum type according to the two-dimension plane.

The invention provides a multilayer sandstone reservoir low-resistivity oil layer identification method and device. The method comprises the steps that a target exploration zone is subjected to reservoir stratum type classification according to seismic data and subjected to oil-water layer identification, and a questionable low-resistivity oil layer is determined; according to the trap formation, the oil and gas reservoir type of the position of the questionable low-resistivity oil layer is determined; the oil and gas reservoir type is subjected to accumulation mechanism analyzing treatment, and whether the accumulation condition of the oil and gas reservoir type is met or not is judged; if yes, all sand bodies in the position of the questionable low-resistivity oil layer are subjected to unit subdivision with oil and gas reservoirs as units; and in a single oil and gas reservoir, the seal level elevation of the questionable low-resistivity oil layer and the oil-water interface of the reservoir where the questionable low-resistivity oil layer is located are read, and the oiliness of the questionable low-resistivity oil layer is identified. According to the embodiments of the invention, the low-resistivity oil layer in the single oil and gas reservoir can be identified, and the multilayer sandstone reservoir low-resistivity oil layer identification precision can be effectively improved.

The invention discloses a stereoscopic compound cultivation method for a rice field in order to solve problems of weaker ecological adaptability, single product structure and lower economic efficiency of the traditional planting mode. The stereoscopic compound cultivation method comprises the steps of: firstly, consolidating and ruralizing land, and digging a reservoir type fishpond in the center of the field; and secondly, ridging the fully fertilized field, planting seedlings on the side surface of a ridge, culturing fishes in the reservoir type fishpond, culturing ducks in the ridge of the rice field, and culturing chickens on the ridge of the rice field, and carrying out field management until properly harvesting. According to the invention, the comprehensive production capability of the rice field is efficiently enhanced, the adjustment of the agricultural production structure is promoted, both production and income are increased, the comprehensive operation is developed and the yield of the unit area is efficiently enhanced.

The invention relates to a multifunctional three-dimensional physical simulation experimental apparatus for thermal recovery by steam injection. The apparatus comprises a three-dimensional model body, a temperature control box, an injection and recovery device, an energy storage and buffer device and a data collector; the three-dimensional model body comprises an inner chamber and an outer chamber connected in a sleeving manner; an annulus is provided between the inner chamber and the outer chamber; the annulus is used as part of energy buffering so as to better accumulate and release energy during steam huff and puff; a perforation combination of the three-dimensional model body allows simulation of different well types, reservoir types and injection fluid combinations; the three-dimensional model body is moved into the temperature control box, simulation study on development manners and development mechanisms under different reservoir temperatures is achieved by changing the interior temperature of the temperature control box; the apparatus is suitable for the physical simulation of the heat injection development of heavy oil reservoirs with bottom water; experimental conditions are provided for the study on different injection fluids, well pattern types and development modes.

The invention provides a method and system for testing the oil-gas-water profile of each section of a horizontal well by using environmental protection type tracers. The method comprises the steps that according to information containing the oil and gas reservoir type, the fracturing fluid type and the number of test sections, the kinds and the compositions of the chemical tracers are determined;the designed using quantity, the injection time and the injection velocity of the chemical tracer used at each section are determined; injection equipment of the tracers used for testing is determined, and the connecting process of equipment for completing on-site operation is determined and laid out before construction; injection operation of the corresponding chemical tracers required by construction sections is completed according to the designed pump injection procedure; after fracturing construction of the whole horizontal well is completed, continuous tracer test sampling operation is implemented according to the designed sampling time and frequency, and samples are tested in time after all sampling is completed; and a production profile map or a contribution ratio map of each layersection of the oil and gas reservoir horizontal well within the sampling period is drawn.

The invention discloses a precise reservoir prediction method based on waveform classification and retrieval under forward constraints. The method comprises the steps of selecting an effective range and converting large-region multi-phase spread into micro-region single phase spread; dividing a reservoir in the single phase spread into different types, and summarizing sedimentary characteristics of different types of reservoirs and post-stack seismic reflection characteristics; simulating a typical waveform of each type of reservoirs via wave equation forward modeling; performing frequency expanding treatment on the single phase spread seismic data by using well control mixed phase wavelet deconvolution; performing primary waveform classification on a single phase spread range by using a non-supervision neural network classification method; and reconstructing a waveform model trace, re-classifying the waveforms, and implementing waveform retrieval. According to the method provided by the invention, a corresponding relation between the reservoir types and the waveforms is built by wave equation forward modeling, and the waveforms are primarily classified and then retrieved to achieve precise prediction of the different types of reservoirs in the phase spread, so that the method is the effective and rapid precise prediction technology for recognizing the different types of reservoirs in the same phase spread in a small range.

The invention relates to a composite hydrodynamic reservoir bank slope stability prediction method, which belongs to the technical field of slope stability evaluation and landslide disaster monitoringand early warning. The method comprises the following steps of preliminary investigation of a reservoir-type landslide, selection of a displacement monitoring point, arrangement and installation of monitoring equipment, processing of monitored data, determination of landslide basic physical and mechanical property parameters and a slope slicing method, determination of overall residual downward thrust increment of the slope above a water line under effects of rainfall, determination of a slope saturation line during a reservoir water line decreasing process, determination of residual downwardthrust increment of the slope in a water line change range under effects of the reservoir water line, determination of reservoir-type landslide composite water loading and response parameters, determination of a composite hydrodynamic increased load displacement response ratio prediction model, and evaluation and monitoring and early warning of the composite hydrodynamic slope stability. The corresponding relationship between the reservoir-type landslide composite hydrodynamic increased load displacement response ratio parameters and the landslide stability is disclosed, and on the basis, a reservoir-type slope stability evolution law is analyzed and evaluated.

The invention provides a geographical physical characterization method for channel sand reservoir type oil and gas gathering conditions. The geographical physical characterization method for the channel sand reservoir type oil and gas gathering conditions comprises the following steps of (1) constructing ridge characterization; (2) describing an oil source fracture net; (3) performing batched sand automatic track; (4) performing fracture and sand configuration analysis; and (5) comprehensively predicting favorable oil-bearing areas. By the geographical physical characterization method for the channel sand reservoir type oil and gas gathering conditions, reasonable characterization and comprehensive analysis can be carried out through an advanced mathematical algorithm and a signal processing means, macroscopic favorable oil-bearing areas are indicated, and a potential exploration target can be provided on the basis of geological analysis and comprehensive assessment of an oil and gas detection result.

The invention provides a method and device for establishing a carbonate rock reservoir space model. The method comprises the following steps: obtaining seismic longitudinal wave transmission signals; subjecting the seismic longitudinal wave transmission signals to correction, amplitude preservation and prestack time migration processing; determining a seismic wave reflection abnormality area in atarget interval according to the processed seismic longitudinal wave transmission signals; determining the approximate position for reservoir development according to the seismic wave reflection abnormality area in the target interval; determining the type and the developmental characteristic of the reservoir near to the wellbore of the target interval according to the combined logging data and the logging curve characteristic; determining the type and the developmental characteristic of the reservoir far from the wellbore of the target interval according to the pressure recovery well testingdata, the pressure recovery well testing pressure and the pressure reciprocal double logarithmic curve characteristic, and constructing the space model of the reservoir according to the approximate position for reservoir development, the type and the developmental characteristic of the reservoir near to the wellbore of the target interval and the type and the developmental characteristic of the reservoir far from the wellbore of the target interval. Due to the adoption of the method and device for establishing the carbonate rock reservoir space model, the reservoir description accuracy can beimproved.

The invention relates to the technical field of petroleum exploration and development, in particular to a technology for thin layer lithology reservoir recognition and horizontal well drilling tracking. The technology comprises the steps of applying newly collected three-dimensional seismic data, carrying out comprehensive geological research by combination of well logging of a newly drilled well and production data, studying oil reservoir types and distribution laws, confirming reservoir-controlling factors, and finely depicting a geologic body; utilizing the high-yielding well reflection characteristics to track a favorable sand body, utilizing the fact that a high-yielding well has the reflection characteristics of ranging from points to lines, faces, and bodies on a seismic section, namely the characteristic that sand body updip pinch-out points and horizontal change points form sand body pinch-out lines is obvious, and determining a sand body distribution range in an own style. The thin layer lithology sand body of smaller than 5m can be effectively depicted, the oil reservoir thickness lower limit deployed by a horizontal well is reduced from 5m to 1.6m, and thin layer marginal oil reservoir reserves are effectively applied. The shortcoming that the thin layer marginal oil reservoir reserves cannot be developed in the prior art is overcome.

The invention relates to a dynamic visualization observing device for a displacement experiment. The dynamic visualization observing device comprises a fluid pumping-in device, a middle piston container I, a middle piston container II, a rock core slice, a fluid collecting container, a dynamic visualization micro model and an observing assembly. The middle piston container I and the middle piston container II are connected in parallel between the fluid pumping-in device and the rock core slice, and the rock core slice is arranged inside the dynamic visualization micro model. The dynamic visualization micro model is prepared from polydimethysiloxane, an oil and water injection opening and a liquid discharging opening are formed in the parts, with the equal distance to the center, on the two sides of the center of an upper model body respectively, the rock core slice is embedded in the center of a lower model body in a pressing mode, and thus a groove with the shape and dimension the same with those of the rock core slice is formed. The device is simple in structure and convenient to operate; the rock core slice is fixed by heating and softening the lower model body, the oil and water dynamic moving rules and distribution situations of different reservoir types are observed through different rock core slices, and then schemes for exploiting oil pools and increasing the oil recovery are made in a targeted mode.