94 results about "Fluid migration" patented technology

The invention relates to the technical field of mineral resource reserve simulation, in particular to a geological mineral resource reserve simulation method. The method comprises the following steps: carrying out multi-source heterogeneous data acquisition on a target geological area, and carrying out comprehensive feature extraction to obtain a comprehensive data set; constructing an initial static geologic model according to the comprehensive data set to obtain the initial static geologic model; building a multi-physics field coupling model according to the initial static geologic model to obtain a multi-physics field coupling model grid; performing metallogenic fluid migration and enrichment simulation according to the multi-physics field coupling model grid to obtain a metallogenic fluid migration simulation result; carrying out geologic body geometrical morphology updating on the initial static geologic model according to a metallogenic fluid migration simulation result to obtain a dynamic geologic model; and performing reserve prediction model training according to the dynamic geologic model to obtain a reserve prediction model. According to the method, the mineral resource reserves are evaluated more accurately and dynamically through a mineral resource reserve simulation technology.

The invention relates to the technical field of mineral resource exploration. The prospecting method, device and equipment based on the multi-source geological relation data and the medium are provided, the method comprises the steps that space-time alignment and standardization processing are conducted on obtained geological historical evolution data, geophysical field data, geochemical migration data and remote sensing alteration information, and a dynamic knowledge graph is generated; performing mineralization stage division processing on the geological historical evolution data to obtain a mineralization stage division result; integrating the fluid migration space-time path network, performing three-dimensional dynamic modeling processing, and generating a staged three-dimensional metallogenic evolution model; extracting a stage-specific geological mark combination from the staged three-dimensional metallogenic evolution model, performing knowledge reasoning processing based on a preset historical ore deposit rule base, and outputting an ore prospecting target region and a metallogenic process constraint basis which meet a preset confidence coefficient condition, so as to improve the precision of a structural model, generate a staged fluid dynamic field, and improve the precision of the metallogenic process. And the target region prediction confidence is enhanced.

The invention discloses an oxidation leaching system and method for argillaceous sandstone uranium ore. The system comprises a uranium leaching pool, a recovery pool, a liquid preparation-dosing unit pool and an intermediate pool. Wherein the uranium leaching tank is provided with a water dispersing layer, a uranium ore layer and a liquid collecting layer from top to bottom, and efficient oxidation of uranium ore is achieved through coupling of oxygen and ferric iron; the recovery pool is sequentially provided with a resin adsorption layer and a water inlet layer from top to bottom, and efficient recovery of uranium in the leachate is achieved; the liquid preparation-dosing unit pool is provided with an acid-resistant submersible sewage pump used for circularly conveying the ore leaching liquid to the uranium leaching pool and adjusting the pH value of the ore leaching liquid and the initial concentration of Fe < 3 + >. And the middle tank drives the ore leaching liquid to form periodic tidal flow circulation in the uranium leaching tank through an acid-resistant submersible sewage pump. According to the system and the method, tidal flow regulation and control, aeration oxygen supply enhancement and iron ion circulation oxidation technologies are coupled, and the uranium leaching rate gt of the argillaceous sandstone uranium ore is achieved by establishing a multi-stage oxidation field domain, optimizing a fluid migration path and establishing an iron element regeneration mechanism; 92%.

The invention discloses a deep geothermal fluid cause and migration path tracing method, and relates to the technical field of earth scientific exploration, and the method specifically comprises the following steps: A1, collecting a geothermal fluid sample, A2, fusing high-precision three-dimensional seismic data, logging data and drilling data, constructing a multi-scale fracture network model, quantifying fracture connectivity and permeability anisotropy, and calculating the fracture connectivity and permeability anisotropy according to the fracture connectivity and permeability anisotropy. A3, developing a long short-term memory (LSTM) network model, inputting temperature, pressure and chemical field data monitored in real time, dynamically predicting a fluid migration path, and introducing a generative adversarial network (GAN) optimization model, and A4, deploying a distributed optical fiber sensor network. According to the sensing method for the aviation high-speed moving target, through the core-shell structure tracer agent, high fluorescence efficiency and geological compatibility are considered, a complete innovation chain is formed in the aspects of material design, detection method and environmental adaptability of the nano tracer agent, and the precision and sustainability of tracing of a migration path of deep geothermal fluid are remarkably improved.

The invention relates to a shale reservoir oil-gas migration capability evaluation method, which is used for evaluating oil-gas migration capability by taking an arithmetic square root of a fluid adsorption inhibition index and a pore diameter contribution index of rock as an oil-gas migration capability index. 0 lt; when the oil-gas migration capability index is less than or equal to 0.35, the oil-gas migration capability is class III, and the oil-gas migration capability is poor; 0.35 lt, 0.35 lt; when the oil-gas migration capability index is less than or equal to 0.70, the oil-gas migration capability is class II, and the oil-gas migration capability is medium; 0.75 lt, 0.75 lt; when the oil-gas migration capability index is less than or equal to 1, the oil-gas migration capability is class I, and the oil-gas migration capability is good. According to the method, the favorable factor aperture contribution index influencing the fluid migration capability and the adverse factor rock-to-fluid adsorption inhibition index are combined for comprehensive evaluation for the first time, the oil-gas migration capability index is calculated, the division standard is established, and quantitative evaluation of the oil-gas migration capability of the shale reservoir is realized.

The invention discloses an experimental device and method for controlling migration and mineralization of ore-forming fluid in a wrinkle deformation process, and belongs to the technical field of ore deposit geology. The device comprises an ore liquid synthesis unit and a mechanical deformation simulation and mineralization analysis unit. The mechanical deformation simulation unit comprises a box body, an extrusion deformation system, a liquid injection system and a heating temperature control system, and can synchronously realize visual analysis of structure extrusion, fluid injection and mineralization precipitation at high temperature. The experimental method comprises the following steps: firstly, preparing a simulated metallogenic fluid containing FeS2 (pyrite); laying simulated surrounding rock and wrinkles in the box body, arranging a separation layer, and heating; extruding the sand layer and injecting fluid to simulate a mineralization process; and slicing, sampling and analyzing after model consolidation, and establishing a mineralization space distribution model. The device is simple in structure and convenient to operate, the whole process of fold extrusion, crack extension, fluid migration and mineral precipitation can be repeatedly represented, and an experimental basis is provided for hydrothermal deposit mineralization mechanism research and prospecting prediction.

The invention discloses a CO2-EGR visual monitoring method based on nuclear magnetic resonance. The CO2-EGR visual monitoring method aims at solving the problem that dynamic observation of the pore scale gas drive process is insufficient in the traditional technology. Multi-sequence nuclear magnetic resonance monitoring is synchronously executed, a T2 spectrum is obtained through a CPMG sequence to analyze CH4 content changes, a layered T2 spectrum is generated through an SE-SPI sequence to represent axial fluid distribution, a one-dimensional frequency signal is collected based on a GR-HSE sequence to track a displacement leading edge in real time, and fluid migration visualization is achieved in combination with an HSE overall imaging sequence. The system integrates a gas injection unit, a high-pressure-resistant nuclear magnetic holder, a back pressure controller and a data acquisition module, and is hermetically connected through a high-pressure-resistant pipeline to form a closed-loop experiment system. According to the method, displacement front recognition, displacement process in-situ analysis and quantitative characterization of the displacement efficiency in the non-intrusive CO2-EGR process are achieved for the first time, the CO2-EGR visualization bottleneck is broken through, and a scientific basis is provided for optimizing gas injection parameters and improving the natural gas recovery rate and the carbon sequestration efficiency.

The invention discloses a dominant flow evaluation method based on tracer migration. According to the method, in the design process, the influence of soil layer permeability difference on the tracer breakthrough curve is fully considered, and a systematic tracer breakthrough curve calculation method and a qualitative judgment process are provided. And predicting the change trend of the breakthrough curve through a numerical simulation test. According to the method, the accuracy of breakthrough curve judgment can be effectively improved, and the method is suitable for tracer migration analysis under different types of soil layers and complex geological conditions. By means of the method, the diffusion and dominant flow migration process of the tracer agent can be better evaluated, and reliable data support is provided for underground fluid migration and pollution monitoring.

The invention provides a method for quantitatively evaluating tight sandstone oil-gas migration based on multi-physics field simulation numerical simulation, which comprises the following steps: comprehensively judging the reservoir forming period of a research area through a fluid inclusion uniform temperature experiment in combination with a Petromod basin numerical simulation result; on the basis of obtaining the reservoir forming period of the oil reservoir, determining the porosity, permeability and pore pressure of the reservoir forming period of the oil reservoir; on the basis of obtaining the porosity, the permeability and the pore pressure in the reservoir forming period of the oil reservoir, constructing a finite element plane model of the research area by utilizing Comsol multi-physics field simulation software, constructing a porosity, permeability and pore pressure interpolation function, and carrying out fluid migration by adopting a Rietz equation; and comparing the actual distribution condition of the oil reservoir in the research area with the peak convergence area of the fluid pressure field and the fluid velocity field obtained by simulation to judge a potential oil reservoir distribution area. The result obtained by the method provided by the invention is more accurate and more scientific than the result obtained by determining the upper limit of the well drilling burial depth of the favorable area only by experience in the past.

The invention discloses a CCUS experimental device and method for carbon dioxide flooding and storage, and relates to the technical field of petroleum engineering. The device comprises a three-dimensional oil reservoir physical model, a fluid injection system, a fluid collecting and metering system, a resistivity monitoring system and a fluid migration observation system. The three-dimensional oil reservoir physical model is used for constructing a simulated stratum, and a development well pattern system is installed on the simulated stratum; the fluid injection system is connected with the injection well; the fluid collecting and metering system is connected with the production well; the resistivity monitoring system is provided with a plurality of monitoring points on the simulated stratum; the fluid migration observation system is used for observing a migration path of supercritical carbon dioxide in the three-dimensional oil reservoir physical model; and the distributed optical fiber monitoring system is arranged in the simulated stratum. According to the device and the method, oil reservoir water injection exploitation and CO2 injection oil displacement and CO2 storage stability simulation experiments in the later development period can be realized.

The disclosed methods include: determining a central reference point for fluid migration associated with the stored subsurface fluid; generating a radial coverage detection space extending from the central reference point for the fluid migration associated with the stored subsurface fluid; initializing a subsurface computing model for the stored subsurface fluid; overlaying the radial coverage detection space or detection system over the subsurface model for the stored subsurface fluid; execute one or more simulations by adapting or varying the one or more parameters of the subsurface computing model based on fluid plume data or fluid pressure data associated with the stored subsurface fluid; generating, based on the fluid plume data or fluid pressure data, spatial or temporal fluid distribution data associated with the stored subsurface fluid; and generating, based on the spatial or temporal fluid distribution data, PP data and PS data associated with the stored subsurface fluid.

The invention provides a nuclear magnetism-resistivity combined measurement method for occurrence and migration of fluid in a rock core. The nuclear magnetism-resistivity combined measurement method comprises the steps that the rock core is dried and cooled to the room temperature; applying a specified confining pressure to the rock core and keeping the confining pressure constant; measuring background resistivity distribution of the rock core, and closing the resistivity analyzer; opening a liquid pump and a liquid inlet valve, and stopping pumping when the liquid level of the fluid is flush with the upper surface of the sponge; performing nuclear magnetic resonance imaging on the rock core, dividing the rock core into a plurality of observation sections in the longitudinal direction, and ensuring that at least one observation section is formed at the place with the conductivity probe; turning off the nuclear magnetic analysis system and the nuclear magnetic resonance imaging system, and measuring the resistivity of the rock core; nuclear magnetic measurement and resistivity measurement are carried out alternately; calculating a fluid migration rule in a spontaneous imbibition process to simulate a soaking process; and calculating a fluid migration rule in a gas driving process, and realizing nuclear magnetism-resistivity combined measurement of fluid occurrence and migration. The method can effectively avoid the interference of magnetic polarization on the resistivity test in the nuclear magnetic measurement process, and is high in measurement precision.

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 invention discloses a structure-permeability coupling simulation device, system and analysis method for a fault zone, belonging to the field of geological simulation of oil and gas reservoirs. The simulation device includes a deformation simulation system, a fluid injection system and a terminal control system. The terminal control system controls the deformation simulation system to deform, so as to form a fault zone in the formation, simulate the formation process of the fault zone, and a fluid injection system is provided, which can inject fluid during the formation process of the fault zone or after complete deformation, so as to realize the whole process of simulating the migration and accumulation of fluid in the formation and the fault zone, and thus determine the continuity of shale smear and the relative permeability of the fault zone according to the fluid migration and accumulation process. The critical value for maintaining the continuity of shale smear can also be determined by using the shale smear continuity characterization algorithm based on the fault zone structure characteristic data obtained from multiple experiments, and at the same time, the control factors of shale smear continuity and fault zone permeability are analyzed, providing a basis for fault sealing evaluation and oil and gas exploration and development.

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 provides a CO2 migration and storage state monitoring method, system, medium and equipment, and belongs to the field of geophysics comprehensive application. The method comprises the following steps: firstly, respectively calibrating a target interval of CO2 sequestration through different observation systems, and analyzing a difference change range caused before and after CO2 injection through annular VSPs in different directions to obtain a migration boundary of a gas injection well; secondly, processing the ground two-dimensional seismic survey lines before and after CO2 injection by adopting the same processing parameters; and finally, performing qualitative analysis on the states before and after CO2 storage by adopting frequency attribute analysis and impedance inversion results, thereby realizing CO2 migration and storage state monitoring. According to the method, a CO2 monitoring closed loop is formed from collection to processing to explanation by adopting a geophysical monitoring means, and fluid migration and storage states before and after gas injection can be effectively compared by collecting changes of related attributes after reservoir fluid changes.

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.

The invention discloses a centrifugal test device for the migration research of water-sand mixed fluid, and the device comprises a material source box module which simulates the supply of a water source and a sand source, and carries out the dynamic monitoring of the state of the material source through a water pressure sensor, an earth pressure sensor and a displacement sensor; the sand-bursting channel module is formed by combining a transparent acrylic front plate and an aluminum back plate, and a water pressure sensor and a temperature sensor are embedded in the sand-bursting channel module to simulate the water-sand migration process in fractures with different geometrical shapes; the collecting box module is used for receiving the outflow water-sand mixture, a water pressure sensor is arranged inside to monitor the residual pressure of the outflow end, and a weighing sensor is arranged outside to calculate the fluid mass change of the water-sand mixture in real time in a high-g environment; and the data acquisition module is used for acquiring water pressure, stress, vibration, acceleration and temperature signals and acquiring sand accumulation behaviors and interface flow characteristics through image comparison and analysis. The device is adjustable in channel structure, controllable in hydraulic condition, diversified in monitoring means, high in test precision and suitable for various water inrush and sand inrush disaster mechanism research scenes.

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.

The invention discloses a coal mining three-dimensional simulation method based on a numerical manifold and a structured grid, and belongs to the field of coal mining three-dimensional simulation. The method comprises the steps that the initial position of a working face is determined, and a field database is collected; performing grid division on the calculation area, and fusing the field database to obtain a grid model fused with the field data; constructing and coupling a grid model of numerical manifold coverage and fusion field data; coupling of fracture mechanical behaviors and seepage is achieved; based on the CPU-GPU heterogeneous parallel structure, solving a three-dimensional stress field, a displacement field and a pore gas pressure field evolved along with time of the current calculation area; and advancing the coal mine working face in the next step until the whole advancing of the working face is completed, and obtaining the stress distribution change, the fluid migration change and the fracture extension change in the whole advancing process of the working face. The method solves the problems that the existing method is difficult to describe the stress accumulation of the initial microfracture with high precision and is difficult to maintain the topological update of contact / separation after fracture.

1. The name of the product of this design: magnetic resonance imaging analyzer. 2. Purpose of this design product: used to measure the microscopic pore structure, fluid content and fluid migration of inorganic non-metallic materials. 3. The design key point of this appearance design product lies in the shape. 4. The picture or photo that best illustrates the design points: three-dimensional picture.

The present invention belongs to the technical field of petroleum development, and specifically relates to a method for making a microscopic glass model of heterogeneous rock pores. The method includes, during the process of making an image negative film, obtaining a pore map with different permeability gradients based on a thin film image of a cast body of a core with different permeabilities to make a negative film; converting the width of the pores in the high permeability zone according to the depth requirements of the design, obtaining a contracted size, and performing photoetching on a chrome plate; etching glass to form three-dimensional channels of different depths, first etching several shallow depth zones, one part as a low permeability zone and one part as a high permeability zone; sealing the channels etched as the low permeability zone portion; and etching the channels etched as the high permeability zone portion a second time to form high permeability zone channels. The model made by the method of the present invention has three-dimensional channels of varying depths, which can simulate the actual situation of fluid migration in the channels, reflecting the difference in permeability not only in the plane but also in the vertical direction.

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 present invention discloses a system and method for oxidative leaching of argillaceous sandstone uranium ore. The system includes: a uranium leaching pool, a recovery pool, a liquid preparation - chemical addition unit pool, and an intermediate pool. Among them, the uranium leaching pool is hierarchically provided with a water - spreading layer, a uranium ore layer, and a liquid - collecting layer from top to bottom, and high - efficient oxidation of uranium ore is achieved by coupling oxygen with ferric iron. The recovery pool is sequentially provided with a resin adsorption layer and a water - inlet layer from top to bottom to achieve high - efficient recovery of uranium in the leaching solution. The liquid preparation - chemical addition unit pool is equipped with an acid - resistant submersible sewage pump, which is used to circulate the ore - leaching solution to the uranium leaching pool and adjust the pH and the initial concentration of Fe 3+ in the ore - leaching solution. The intermediate pool drives the ore - leaching solution to form a periodic tidal flow circulation in the uranium leaching pool through an acid - resistant submersible sewage pump. The system and method of the present invention couple tidal flow regulation, aeration oxygen supply enhancement, and iron ion cyclic oxidation technologies. By establishing a multi - level oxidation field, optimizing the fluid migration path, and establishing an iron element regeneration mechanism, the uranium leaching rate of argillaceous sandstone uranium ore is > 92%.

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 present disclosure provides a method and system for simulating and predicting sudden water inrush applicable to different geological media, which relates to the technical field of simulating and predicting sudden water inrush, including constructing a medium model based on actual geological conditions and a particle discrete element method; analyzing the force changes of particle contact in the medium model to obtain geometric information of the medium characteristic structure and the connectivity of the medium structure; constructing the topological structure of the medium model through a graph theory pipe network method, and performing fluid mechanics calculations to determine the fluid pressure and flow distribution; introducing a mapping algorithm based on nearest point search and a pressure interpolation method to feed back the fluid pressure and flow distribution information to the medium model, updating the hydraulic conditions in the medium model, and realizing the dynamic coupling of water flow and particle motion in the medium; establishing a coupling feedback mechanism between the medium model and the fluid pressure and flow distribution, updating the interaction between particle motion and fluid migration in real time, and realizing the simulation prediction of sudden water inrush.

The invention belongs to the technical field of oil and gas reservoir development physical simulation, and relates to an experimental device and method for simulating shale fan-shaped well pattern optimization in a high-temperature and high-pressure environment, and the experimental device comprises a high-temperature and high-pressure bin, a heterogeneous semi-cylinder model, a fan-shaped well pattern, a fluid injection assembly, a saturation and pressure monitoring assembly and a temperature control assembly. According to the device, coal oil is pumped into a high-temperature and high-pressure bin through a fluid injection assembly to achieve a high-pressure environment, a fan-shaped well pattern is arranged on a heterogeneous semi-cylinder model, cracks are formed in a horizontal well section, and fluid is injected through a central vertical well section; data are collected in real time through the saturation and pressure monitoring assembly, the high-temperature and high-pressure stratum environment is simulated in combination with the temperature control assembly, and therefore the fan-shaped well pattern spacing, the horizontal section length and the crack number are optimized. According to the invention, the fluid migration rule of the shale reservoir under the complex well pattern structure can be effectively simulated, and an optimization design basis is provided for shale gas development.

This invention belongs to the field of research on the landward distribution boundaries of natural gas hydrates. It discloses a method and system for studying the fate of methane at the landward distribution boundaries of marine natural gas hydrates, including: seismic interpretation and attribute analysis of present-day BSRs; seismic interpretation and attribute extraction of ancient BSRs to calculate their development depths; calculation of the hydrostatic pressure at the time of the ancient BSRs; simulation and prediction of the ancient BSR positions to determine the location of the landward distribution boundaries of the ancient hydrates; demarcation of the main areas of the study area; identification of whether submarine seepage features are present near the landward distribution boundaries of the hydrates, and interpretation of possible vertical and lateral fluid migration pathways and free gas accumulation; determination of the fate of methane at the boundaries and analysis of the main controlling factors; and calculation of the hydrate decomposition zone volume at the landward distribution boundaries of the hydrates based on the positions of the ancient and present BSRs. This invention identifies multiple types of methane fates at the landward distribution boundaries of marine natural gas hydrates, enabling a correct understanding of the environmental impacts of different methane fates and their effects on hydrate reservoirs.