37 results about "Fluid migration" patented technology

The invention discloses a new-type barite deposit mineralization mode construction method based on a same sedimentary fault. The method belongs to the field of geological exploration and mineral resource prediction, and comprises the following steps: analyzing the earth crust cracking activity history of an earthquake-Hangjian broken basin, and recovering a basin'checkerboard 'structure prototype; by means of field geological survey and research, drilling engineering, geophysics, remote sensing geological big data and the like, north-east-east-direction and north-west-direction co-sedimentary fault networks are identified and modeled, and a deep metallogenic fluid rising and jet flow channel is determined; the metallogenic process is concluded into a hydrothermal jet flow stage and an underwater gravity flow deposition stage, deep fluid is revealed to rise, jet flow and precipitate along a fault, and an ore-rich zone of a composite seabed fan body group is formed; and a geochemical prospecting prediction model combining trace element and sulfur isotope characteristics is established. The method systematically clarifies a coupling mechanism of ore control of the same sedimentary fault, ore-forming fluid migration and gravity flow deposition, and provides a theoretical basis and a technical means for prospecting prediction of the barite deposit in the Hendan-Hangjian fault basin.

A composite vessel and fitting for a through-wall penetration having an exposed end grain. The fitting includes a sealing surface arrangement that seals against the composite vessel and prevents leakage of the vessel contents while protecting the end grain from exposure to internal fluid and / or external environment. The fitting includes an outer part, an inner part, and a through-wall part extending between the inner and outer parts across the penetration. An outer seal arrangement includes an outer seal having a first sealing surface that seals against the outer surface of the composite vessel to restrict environmental contaminants migrating to the end grain. An inner seal arrangement includes at least one inner seal having second and third sealing surfaces. The second sealing surface seals against the inner surface of the composite vessel and the third sealing surface seals a leak path or interface between the inner part and through-wall part to restrict internal fluid migrating to the end grain.

The present application relates to geothermal resource development and evaluation technical field, especially to the balanced water and heat type geothermal resource dynamic evaluation method, including: collecting the flow, temperature and pressure data of the produced fluid and the recharging fluid, and carrying out time synchronization, outlier elimination and time series reconstruction processing on the data to form a continuous operation data set; jointly analyzing the time series change of the operation data set, extracting flow response characteristic quantity and heat exchange response characteristic quantity, and dividing the underground heat reservoir into flow and heat storage units according to the similarity of the characteristic quantity; on the scale of the flow and heat storage unit, respectively establishing a flow structure model and a heat exchange structure model, and coupling them, through a unified state variable to describe the corresponding relationship between the fluid migration behavior and the energy transfer behavior, a flow and heat storage dynamic evaluation model is constructed; based on the model, the change of the state variable of each flow and heat storage unit with time during the recharging operation process is calculated, and the dynamic evaluation data is obtained.

The invention discloses an online analysis experiment system for simulating fluid migration and component change under multi-scene multi-medium multi-field coupling, which comprises a model unit and a fluid conveying unit, and the fluid conveying unit injects experiment fluid into the model unit. Each model unit structurally comprises a cylindrical shell with two open ends, a rubber cylinder is arranged in the shell, an annular space between the rubber cylinder and the shell is sealed, experimental fluid can be directly injected into the rubber cylinder, or experimental fluid can be injected into the rubber cylinder after a rock core or a sand filling model is placed, and a plurality of monitoring holes are formed in the side wall of the rubber cylinder at equal intervals. The sampling holes are communicated with the corresponding round pipes on the shell to serve as monitoring channels or sampling holes, and sealing covers or monitoring sensors are selectively installed on the monitoring channels. The experiment system can test and analyze fluid mixing and mixing zone change, displacement migration, component change and other conditions under multi-scene multi-medium multi-field coupling on line, for example, the experiment system is used for oil and gas displacement, gas storage injection and production simulation, underground energy storage and other experiment researches.

This invention relates to the field of drilling and completion fluid semi-permeable membrane testing technology, specifically a drilling and completion fluid semi-permeable membrane testing device. The device includes a base plate, a vertical plate fixedly connected to the top surface of the base plate, an upstream chamber fixedly connected to the front surface of the vertical plate via a connecting plate, a downstream chamber and an injection cylinder fixedly connected to the top surface of the base plate, and a core holding chamber integrally connected to the top surface of the downstream chamber. The inner bottom surface of the core holding chamber has a through hole. This drilling and completion fluid semi-permeable membrane testing device provides active fixation and circumferential sealing of the core, preventing fluid migration or core displacement under high pressure. It also simulates the high-temperature and high-pressure environment downhole, improving the accuracy of drilling and completion fluid semi-permeable membrane testing.

This invention relates to a method for determining the migration front and damage distance, and a fracturing simulation system, relating to the field of oil and gas field development. The method includes: controlling an injection device to sequentially perform carbon dioxide injection, fracturing fluid injection, and well shut-in operations on a core sample to simulate a carbon dioxide pre-fracturing process; at each stage of the simulation, controlling a monitoring device to acquire fluid migration data of the core sample; determining the location or migration distance of the carbon dioxide migration front within the core sample based on the fluid migration data; acquiring damage response data for multiple core segments within the reservoir section, the damage response data being used to characterize the cumulative damage degree of the core sample caused by the simulation process; determining damage boundary data of the core sample based on the damage response data; and determining damage hysteresis data, used to characterize the spatiotemporal coupling relationship between carbon dioxide migration and core damage, based on the migration front data and the damage boundary data.

The invention relates to the technical field of oil and gas field development engineering, carbon storage engineering, underground hydrogen storage technology, underground fluid seepage mechanical experiment technology and rock core displacement simulation devices, and particularly discloses a variable-diameter rock core displacement simulation device and method for simulating underground fluid migration in a near wellbore area. In order to solve the problem that a traditional equal-diameter rock core displacement device cannot simulate sudden drop of flow velocity and pressure gradient when fluid in a near wellbore zone flows radially, the device adopts a variable-diameter rock core design, the diameter of the variable-diameter rock core is gradually increased in the flowing direction, and a back pressure control system, a confining pressure system and a multi-point pressure measuring structure are matched. Under the fixed injection flow, the cross sectional area of the rock core is increased, so that the Darcy flow velocity and the pressure gradient are suddenly reduced from the injection end to the output end, and the flowing environment of the immediate vicinity of a wellbore is directly reproduced. The device can directly and efficiently simulate and test the phase state behavior, rheological property and seepage law of complex fluid under the condition of sudden change of the flow velocity and pressure gradient in the immediate vicinity of wellbore, and the engineering representativeness of experimental data is remarkably improved.

The utility model discloses an in-situ testing device for gas-liquid two-phase permeability after hydraulic fracturing, and belongs to the field of unconventional oil and gas development engineering. The device comprises a fluid injection system, a sample loading system, a ground stress loading system, a fracturing system, a fluid recovery system and a data acquisition and processing system, the fluid injection system, the sample loading system and the fluid recovery system are sequentially connected, the crustal stress loading system is connected with the sample loading system through a rigid pressure head and applies three-dimensional crustal stress to a test piece, and the fracturing system is connected with the sample loading system through a fracturing pipeline and applies liquid injection pressure to the test piece; the fluid injection system, the ground stress loading system and the fracturing system are respectively in electric signal connection with the data acquisition and processing system through transmission cables. The gas-liquid two-phase permeability testing device can be used for respectively testing the gas-liquid two-phase permeability under the conditions of different lithology, different ground stress, different fracturing parameters and different permeability parameters, and can more truly reflect the gas-liquid two-phase fluid migration condition in the unconventional oil and gas discharge and production stage.

The invention belongs to the technical field of methane leakage risk evaluation, and discloses a mainland edge methane lateral migration path identification and shallow water scaffold area methane leakage risk evaluation method, which innovatively focuses on a brand new process of deepwater area release-lateral migration-shallow water area leakage. By constructing a multi-factor weighted evaluation model for comprehensively evaluating key parameters such as a deepwater area gas source condition, a fluid migration channel, a'source-leakage 'distance and a shallow water area water depth, relatively accurate quantitative evaluation on the potential that methane at different mainland edges in the world finally enters the atmosphere is realized. The method not only effectively solves the long-standing scientific contradiction of how deep water methane affects the atmosphere under the barrier of a huge thick water layer, but also more scientifically and accurately evaluates the climate feedback effect of the natural gas hydrate and the shallow gas reservoir under the global warming background, and provides a brand-new and crucial analysis tool and decision basis.

The application provides a preparation method of a biomimetic microfluidic device for studying fluid migration in carbonate rock micro-nano cracks, comprising the following steps: step one, analyzing and classifying scanning electron microscope images of carbonate rock core slices by a random forest algorithm to generate a chip design drawing; step two, based on the chip design drawing, adopting soft lithography technology, copying crack structures through a photoresist template and polydimethylsiloxane, and bonding with a glass substrate to form a microfluidic chip; step three, injecting a precursor liquid containing calcite nanocrystal seeds into the flow channel of the microfluidic chip, fixing the crystal seeds by ultraviolet irradiation, and realizing calcium carbonate mineral precipitation by injecting a saturated equilibrium liquid to form a biomimetic microfluidic device. The application can be used for coupling research of all fluids and carbonate rock cracks, and provides a method for restoring the structure of carbonate rock cracks to the greatest extent and a method for cloning the properties of rock surfaces.

The invention discloses a fluid migration prediction method and device based on uncertainty constraints, relates to the technical field of data processing, and mainly aims to solve the problems of poor accuracy and effectiveness of existing fluid migration prediction based on uncertainty constraints. Comprising the following steps: acquiring a noisy data set of a medium of the uranium-containing solution migrated underground, and constructing a convective diffusion physical control model for representing the convective diffusion process of the uranium-containing solution; constructing a joint posterior probability model based on the joint posterior distribution of the noisy data set, the physical consistency likelihood item of the convective diffusion physical control model and the physical residual item of the physical information neural network model; and solving the joint posterior probability model based on variational gradient descent to obtain a particle set of posterior distribution, and predicting the noisy data set according to the particle set and the physical information neural network model to obtain a fluid migration prediction result.

The present application relates to a kind of ore-forming fluid transport and accumulation process simulation experimental device and method, belong to deposit geological technical field.The device is used to simulate the migration path of ore-forming fluid in the internal fault fold structure, transport and accumulation process, the spatial distribution of the formation of ore body / mineralized zone and ore-forming characteristics, explore the occurrence regularity of the internal structure system of ore body / mineralized zone, provide theoretical reference for actual ore body mining.Through systematic experimental research, more comprehensive and profound understanding is provided for deposit geological theory research and practical operation.In actual mineral exploration and development, the use of this simulation device helps to analyze and predict favorable exploration targets and target area, and provides more scientific and reliable technical support for mineral exploitation.

The invention provides a whole-process simulation method and system for tunnel seepage and water and mud bursting, and the method comprises the steps: building a numerical model containing a tunnel and a fault, and building a solid particle and fluid particle system through meshless particles; a random fracture network is constructed and mapped to solid particles, and attributes are assigned according to fracture filling conditions; calculating particle interaction, introducing a seepage-stress coupling model into a fracture region, and dynamically updating seepage characteristics to simulate implicit seepage; judging damage and fracture of solid particles by using a preset criterion, and representing a cracked block by discrete element particles if the condition is met; calculating contact force between discrete element particles and contact force between discrete element particles and undamaged particles, and simulating movement of fractured rocks; bidirectional fluid-solid coupling is established, and whole-process simulation of seepage inoculation, rock mass fracture and water and mud bursting is achieved through time integration. According to the invention, the strong coupling process of rock mass fracture and large deformation fluid migration is seamlessly simulated through DEM-SPH coupling.

The application discloses a method suitable for judging fluid migration direction of hydrothermal deposit, selects hydrothermal deposits with correlation in a study area; collects hydrothermal mineral samples from each hydrothermal deposit, determines and marks corresponding metallogenic stages of each hydrothermal deposit, divides the hydrothermal deposit into pre-mineralization stage, mineralization stage and post-mineralization stage based on the metallogenic stages; respectively tests stable isotopes of the hydrothermal mineral samples in the pre-mineralization stage, the mineralization stage and the post-mineralization stage, judges mineral stable isotope variation rules corresponding to the hydrothermal mineral samples in different mineralization stages; compares and studies the mineral stable isotope variation rules of the hydrothermal mineral samples in each mineralization stage of two or more hydrothermal deposits, regards a direction in which the mineral stable isotope variation rules of the hydrothermal deposits tend to be consistent as a fluid migration direction; selects another isotope for verification; the application regards the stable isotope variation rule as an effective means for tracing the source of the hydrothermal fluid of the deposit.

Disclosed are a test system and method for determining a fluid migration front based on pulse pressure-enhanced distributed strain, which belong to the technical field of CO2 geological storage and oil and gas resource development. The system includes a CO2 displacement brine unit, an optical fiber sensor, a pulse pressure injection unit, a data acquisition and processing system, and the like. By injecting high-pressure gas into the other side of a core, a large pressure difference is instantaneously generated at a two-phase interface, resulting in significant strain changes. These strain changes are monitored by the optical fiber sensor in real time, and a position of a CO2 / brine migration front is analyzed and determined by a data collecting and processing system.

This invention discloses a method for simulating the migration and dissolution routes of paleoacidic fluids in oil and gas reservoirs, comprising: obtaining a structural map of the top surface of the target reservoir; obtaining a lithofacies distribution map of the top surface of the target reservoir; calculating the physical property data of different lithofacies combinations; combining the obtained lithofacies distribution map of the top surface of the target reservoir and the obtained physical property data of different lithofacies combinations, and using a random interpolation method to obtain a physical property distribution map of the top surface of the target reservoir; constructing a paleoacidic fluid migration potential map by combining the obtained structural map of the top surface of the target reservoir and the obtained physical property distribution map of the top surface of the target reservoir; and using hydrocarbon expulsion and oil and gas migration forces to drive the paleoacidic fluids and conduct paleoacidic fluid migration and dissolution route simulation. This invention effectively solves the shortcomings of existing technologies, has low simulation costs, and comprehensively considers the influence of structure, lithofacies, and fluid potential on fluid migration, improving the simulation effect and accuracy, and is beneficial to research and production applications in the field of oil and gas exploration.

The application discloses a kind of based on CT scanning and mercury injection data fusion core geometry model construction method, it is related to oil and gas field development technical field. Including: by three-dimensional CT scanning and image processing algorithm obtains core pore structure data;Through high-pressure mercury injection experiment obtains core pore throat size distribution data;Innovatively, three-dimensional core pore structure data and core pore throat size distribution data are fused, and pore-throat space mapping network is constructed by graph theory, to construct the core geometry model;And combining optimization algorithm dynamically adjusts pore throat size, verifies the core geometry model constructed.This application breaks through the limitation of traditional single experimental method, solves the problem of insufficient precision of core geometry model construction, and provides high-precision input for numerical simulation of fluid migration law in post-polymer flooding reservoir.The error of fluid flow simulation in COMSOL of the core geometry model constructed and experimental measurement result is controlled within ±5%, which is significantly better than traditional method.

The present application relates to the technical field of coal resource exploration, and particularly relates to a deep coal resource intelligent exploration method based on tectonic stress field, comprising: arranging a detection drill hole in an exploration target area, synchronously collecting five types of parameters of tectonic stress, ground temperature, ground pressure, fluid migration rate and coal porosity by using a deep integrated detection device, and gathering and constructing a multi-field basic data sample library of each parameter; calculating a tectonic stress intensity index based on the multi-field basic data sample library, dividing the exploration target area into a stress concentration area, a transition area and a stable area according to the index, and determining a regulation coefficient of tectonic stress on porosity and fluid migration. In the present application, a multi-field coupling correction model dominated by tectonic stress is constructed, and then the real formation physical property parameters are restored, so that the traditional exploration which mostly uses single physical field detection is improved. Since the nonlinear regulation of tectonic stress on multi-physical field is ignored, the problem that the tectonic coal and gas enrichment area cannot be accurately identified in the deep stress concentration area is caused.

The application discloses a real-time monitoring rock core displacement process test system based on optical fiber sensing and a working method thereof, and belongs to the field of oil and gas resource development and greenhouse gas storage. The test system comprises a visual rock core displacement device, an optical fiber sensing monitoring system, a gas injection system, a liquid injection system, a constant-temperature confining pressure control system, a separation and collection system and a data acquisition and analysis device. The fluid migration interface position, the rock core strain distribution field and the temperature field and the like in the rock core displacement process can be monitored in real time through optical fiber sensing, and a visual calibration method is provided. The application is used for exploring the migration characteristics and mechanism of the fluid in the rock core in the displacement process, capturing the displacement wetting interface, and providing reliable test basis and theoretical analysis for real reservoir gas storage.

The invention provides a deep positioning method and system for a variable-grained rock type niobium-tantalum-rare earth deposit, and relates to the technical field of geological exploration and deposit science. The method comprises the steps that rock samples are collected on the basis of delineation of a favorable mineralization area; carrying out petrology and geochemistry comprehensive analysis on the rock sample to obtain an analysis result; carrying out EBSD analysis on the rock sample to obtain a fluid migration dominant channel direction; based on the fluid migration dominant channel direction, reconstructing fluid evolution historical data controlled by the strain state; the analysis result and fluid evolution historical data are synthesized, and large-scale mineralization conditions caused by a structure-fluid coupling mechanism are determined; and on the basis of large-scale mineralization conditions, a tectonic deformation-fluid pulse-rich mineralization composite mineralization model is constructed, and a deep prospecting target area is delineated. According to the technical scheme, the positioning precision and the prospecting discovery success rate of the deep concealed ore body of the type of ore deposit are remarkably improved.

The present application belongs to the field of oil and gas field development, and particularly relates to a multi-scale CO2 flooding oil component migration monitoring device and method. The present application sets a long and thin tube variable diameter assembly to build a displacement path with a length of meters or more. Compared with a conventional short core experiment, the present application can carry out displacement experiments on a longer migration scale, thereby being more conducive to characterizing the long-range migration process of CO2 in a porous medium and the formation and evolution characteristics of a miscible phase transition zone. By sequentially setting a matrix pore section, a micro-fracture channel section and a fault blocking section in the device, fluid migration behaviors in different types of seepage channels, including matrix seepage, fracture dominant channel migration and local blocking effect, can be simulated in the same experimental system, thereby improving the adaptability of experimental results to complex reservoir seepage characteristics. By arranging multi-point sampling units along the displacement direction and combining with gas phase component analysis means, dynamic monitoring of CO2 and hydrocarbon components inside the device is realized.

The present disclosure relates to the technical field of geology, and particularly relates to a karst fluid migration path determination method, device, equipment, medium and program. The method comprises the following steps: classifying a plurality of reference minerals in a to-be-measured region to obtain a plurality of first minerals and a plurality of second minerals, at least part of the first minerals are located in an initial mixing area, and each second mineral is located in a fluid migration area; detecting the content of a plurality of trace elements in each reference mineral; determining the initial mixing area and the migration direction of the karst fluid in the fluid migration area according to the content of each trace element in each first mineral and the content of each trace element in each second mineral, the karst fluid flows through the minerals at a historical time to form the reference minerals; and determining the migration path of the karst fluid according to the initial mixing area and the migration direction. The migration path of the karst fluid can be determined according to the plurality of reference minerals in the to-be-measured region, the karst distribution rule can be obtained, and thus the development effect of the karst reservoir is improved.

The invention discloses an electrophoresis drying room treatment tank liquid heating control method and system, and relates to the technical field of coating processes, and the method comprises the steps: obtaining internal state parameters of an electrophoresis drying room tank liquid, building a tank liquid multi-physical field digital twinborn body, calculating a momentum and energy transport coupling control equation, generating a bath solution global real-time three-dimensional temperature field-flow field associated state space; identifying a deviation region of the fusion process reference range in the current state space, predicting a dynamic evolution track of the deviation region in a future production cycle, and determining an optimal fluid migration path for conveying heat to the target correction region; and on the basis of the optimal fluid migration path for conveying heat to the target correction area, establishing a bath solution heating dynamic optimization model by taking the condition that the uniformity error of the bath solution global three-dimensional temperature field is smaller than a preset threshold value as a process constraint and taking the lowest energy consumption cost as a target, and obtaining an optimal power set value sequence of each independent partition heating module of the bath solution. According to the invention, the intelligence of the production process is improved.

A composite vessel and fitting for a through-wall penetration having an exposed end grain. The fitting includes a sealing surface arrangement that seals against the composite vessel and prevents leakage of the vessel contents while protecting the end grain from exposure to internal fluid and / or external environment. The fitting includes an outer part, an inner part, and a through-wall part extending between the inner and outer parts across the penetration. An outer seal arrangement includes an outer seal having a first sealing surface that seals against the outer surface of the composite vessel to restrict environmental contaminants migrating to the end grain. An inner seal arrangement includes at least one inner seal having second and third sealing surfaces. The second sealing surface seals against the inner surface of the composite vessel and the third sealing surface seals a leak path or interface between the inner part and through-wall part to restrict internal fluid migrating to the end grain.

The present application relates to the technical field of mine safety monitoring and intelligent regulation, and in particular to an intelligent coal mine gas active prevention and control system and method based on an edge computing architecture and fluid migration mechanism. By sinking the edge computing computing power to the sensor end and combining a dynamic channel preemption mechanism based on a gas concentration gradient drive, a microsecond-level priority response to a gas gushing event is achieved, fundamentally solving the problems of response lag, communication interference and inability to dynamically allocate communication resources according to the emergency degree of the physical flow field in the traditional centralized architecture, and significantly improving the real-time performance and reliability of the system.

The present application belongs to the field of physical simulation technology of oil and gas reservoir development, and relates to an experimental device and method for simulating optimization of shale fan-shaped well pattern under high temperature and high pressure environment, comprising: a high temperature and high pressure chamber, a heterogeneous semi-cylindrical model, a fan-shaped well pattern, a fluid injection assembly, a saturation and pressure monitoring assembly, and a temperature control assembly. The device pumps kerosene into the high temperature and high pressure chamber through the fluid injection assembly to achieve a high pressure environment, and the fan-shaped well pattern is arranged on the heterogeneous semi-cylindrical model, with fractures set in the horizontal well section, and fluid injected through the central vertical well section. Real-time data is collected through the saturation and pressure monitoring assembly, and the high temperature and high pressure formation environment is simulated in combination with the temperature control assembly, so as to optimize the fan-shaped well pattern spacing, horizontal section length and fracture number. The present application can effectively simulate the fluid migration law under the complex well pattern structure of shale reservoirs, and provide an optimized design basis for shale gas development.

This invention provides a method for predicting fluid migration behavior during CO2 injection mining of coal seams containing natural fractures, belonging to the field of coalbed methane exploration. The method includes: constructing a flow model suitable for describing fluid migration velocity within fractures and a modified gas-phase mass conservation equation; constructing a geological model of a coalbed methane reservoir containing natural fractures based on exploration data, dividing the model into grids, and setting initial and boundary conditions; and solving for the spatiotemporal evolution characteristics of methane and carbon dioxide concentrations within each grid cell of the geological model based on the modified gas-phase mass conservation equation, obtaining their temporal and spatial distributions. This invention fully considers the influence of the presence of natural fractures in coalbed methane on the migration behavior of methane and carbon dioxide, overcoming the limitations of existing studies that neglect the role of natural fractures, leading to biased prediction results, and achieving accurate prediction of fluid migration behavior during CO2 injection mining of coal seams containing natural fractures.

The invention relates to the technical field of coal resource exploration, in particular to a deep coal resource intelligent exploration method based on a tectonic stress field, which comprises the following steps of: arranging exploration drill holes in an exploration target area, synchronously acquiring five types of parameters including tectonic stress, ground temperature, ground pressure, fluid migration rate and coal porosity by utilizing a deep integrated detection device, and calculating the exploration drill holes; gathering the parameters to construct a multi-field basic data sample library; and calculating a tectonic stress intensity index based on the multi-field basic data sample library, dividing the exploration target area into a stress concentration area, a transition area and a stable area according to the index, and determining a regulation coefficient of the tectonic stress on porosity and fluid migration. According to the method, the multi-field coupling correction model dominated by the tectonic stress is constructed, and then the real physical property parameters of the stratum are restored, so that the problems that the traditional exploration mostly adopts single physical field detection, and non-linear regulation and control of the tectonic stress on multiple physical fields are ignored; and the problem that the tectonic coal and gas enrichment area cannot be accurately identified in the deep stress concentration area is solved.

The invention relates to the technical field of carbon capture and storage, in particular to a quantitative characterization method for connectivity of carbon dioxide in a shale cover layer, which comprises the following steps: simulating a formation in-situ environment for the shale cover layer, carrying out a stepped injection pressure displacement test, and collecting transverse relaxation time T2 spectrums under different displacement pressures; and constructing a T2-Pc two-dimensional joint function based on the capillary pressure Pc and the T2 spectrum, and calculating the carbon dioxide phase connectivity coefficient of each pore throat unit in the T2-Pc two-dimensional spectrum. According to the method, a formation in-situ environment is simulated through a multi-field coupling test system, and synchronous acquisition of the occurrence state and the fluidity of the fluid under in-situ stress is realized by combining injection pressure displacement and nuclear magnetic resonance technologies; by constructing a T2-Pc two-dimensional joint map, a pore structure and fluid migration characteristics are synergistically represented, pore throat units which are geometrically communicated but hydraulically isolated are accurately distinguished, a calculation result is remarkably related to microCT test and CO2 phase endpoint relative permeability, and the representation precision is greatly improved.

The application provides an experimental device and method for reverse structure and fluid migration integration, which comprises an experimental box, a push-pull power mechanism and a fluid injection mechanism. The experimental box is a rectangular box body, and an experimental model simulating a formation structure is arranged in the experimental box. The push-pull power mechanism is connected with the experimental box and pushes and pulls the experimental model in the experimental box to stretch or extrude the experimental model simulating the formation. The fluid injection mechanism injects a dyeing fluid laterally from the experimental model. The application can simulate the extrusion structure deformation process on the stretching simulation result of uniform stress transmission, and can complete the fluid migration simulation without damaging the elastic polymer used in the stretching simulation experiment, so that the effective combination of the reverse structure simulation and the fluid migration simulation of stretching first and then extruding is achieved.