66 results about "Pore fluid" patented technology

The invention discloses an electrical resistance tomography monitoring and image inversion experiment system in a grouting reinforcement process. The system comprises a transparent soil system, a grouting system, an image acquisition system, an electrical resistance tomography monitoring system and a comparative analysis system, the transparent soil system comprises a transparent box body and transparent soil filled in the transparent box body; the transparent soil is prepared from a transparent soil particle material and a pore fluid; the image acquisition system performs three-dimensional image information acquisition on the grouting area, and generates a three-dimensional grouting image after processing; the electrical resistance tomography monitoring system is used for measuring and monitoring the internal conductivity distribution condition of the transparent soil system on line and generating an internal structure chromatogram of the transparent box body through a conductivity distribution diagram; the contrastive analysis system inputs a three-dimensional grouting image and an internal structure chromatogram of the transparent box body; and comparing and analyzing the two, and optimizing the internal structure chromatogram of the transparent box body based on the three-dimensional grouting image according to the analysis result. According to the method, the grouting reinforcement process is dynamically monitored, and the electrical resistance tomography is optimized and feasibly verified.

The invention relates to a method for quantitatively analyzing the evolution period of paleo-pore fluid in a sandstone reservoir, and belongs to the technical field of oil and gas reservoir exploration and development. According to the method for quantitatively analyzing the evolutionary period of the paleo-pore fluid in the sandstone reservoir, core samples with different oiliness are selected at a target position in a target interval of a research area, fluid activity periods are preliminarily analyzed, and then the core sample with the most fluid activity periods is selected as a standard sample; pore fluid evolution analysis can be carried out on a standard sample, the analysis process is shortened, and the precision of recovering pore fluid evolution is improved.

The invention relates to the technical field of oil and gas field exploration and development, in particular to a rock physical model construction method based on SPC lithofacies parameter constraint. The method comprises the following steps: acquiring S-type parameters, P-type parameters and C-type parameters through core data and logging data; performing quantitative analysis on the SPC type parameters and the physical property parameters, and determining the influence of the complex lithofacies sedimentary structure on the physical property of the rock; constructing an SPC improved solid mineral matrix model; constructing a dry rock skeleton model based on multiple pore aspect ratio factors; constructing a pore fluid model; and according to the SPC improved solid mineral matrix model, the dry rock skeleton model and the pore fluid model, on the basis of a Gassmann theory, constructing a rock physical model based on SPC lithofacies parameter constraint. According to the method, the adaptability and accuracy of the rock physical model in different lithofacies prediction processes can be improved; and a communication bridge is built for further predicting the lithology, the physical property and the oil-gas possibility of the reservoir.

The invention provides a sodium ion specific fluorescence labeled transparent soil sample as well as a preparation method and application thereof, and belongs to the technical field of rock soil and geological engineering. The method comprises the following steps: firstly, sequentially carrying out hydrophilization treatment, solvent evaporation and dissolution on a sodion combined benzofuran isophthalate probe to obtain a probe mother solution; mixing the probe mother solution, a buffer solution, an inorganic sodium salt solution and a solvent to prepare a fluorescence labeling pore solution; and finally, mixing the sodium polyacrylate particles and the fluorescence labeled pore liquid, and performing vacuum saturation treatment to obtain the transparent soil sample. The transparent soil sample provided by the invention still keeps excellent optical transparency while having sodium ion specific response capability, so that a stable and reliable experimental medium is provided for in-situ, real-time and full-field observation of sodium ion migration.

The invention discloses a method, a system, equipment and a medium for evaluating the gas-bearing property of a water-flooded area, and the method comprises the steps: confirming three pieces of quantitatively measured skeleton information and fluid medium information in a time domain through different minerals and fluid components, and calculating a fast neutron scattering cross section according to pulse neutron logging data; carrying out qualitative identification on the gas reservoir by combining the fast neutron scattering cross section and the stratum hydrogen-containing index; according to the fast neutron scattering cross section, the thermal neutron capture cross section, the hydrogen content index and the respective volume content, a linear equation set is established, and the simultaneous equation set is solved to obtain the content of different fluid components in the stratum. The gas reservoir evaluation method solves the problem that a conventional gas reservoir evaluation method is seriously influenced by detection depth, borehole environment, invasion, low contrast ratio and pore fluid properties, and does not depend on conventional logging curves and electrical characteristics.

The utility model provides a chromatographic column head with a pore fluid distribution cover, which comprises a column head bottom plate for storing and discharging liquid and a column head top plate covering the top of the column head bottom plate and used for injecting liquid and exhausting, and a water injection pipe for injecting water into the column head bottom plate is arranged in the center of the top of the column head top plate. A groove used for storing liquid is formed in the column head bottom plate, a plurality of liquid drainage holes communicated with the outside are formed in the bottom of the groove in an arrayed mode, a liquid distribution disc structure with the same projection area as the groove is arranged in the groove, and the liquid distribution disc structure is in an arc shape. The circle center of the liquid distribution disc structure and the axis of the water injection pipe are collinear, the liquid distribution disc structure comprises a water avoiding area arranged under the water injection pipe and a liquid distribution area arranged around the water avoiding area, and the area of the water avoiding area is larger than or equal to the projection area of an inner hole of the water injection pipe. A plurality of liquid separation holes are formed in the liquid separation area around the water avoiding area.

The invention belongs to the technical field of mineral calculation and reservoir evaluation, and particularly discloses an electric imaging logging mineral component quantitative characterization method based on porosity spectrum correction, which comprises the following steps: preprocessing original electric imaging logging data, and generating a high-density pixel image; performing probability density statistical analysis on the pixel value of each depth point in the high-density pixel image to obtain a pixel waveform spectrum; calculating the apparent porosity of each pixel point in the high-density pixel image to generate a pore spectrum; performing pore fluid influence correction on the original electrical imaging data based on the pore spectrum, performing image enhancement to generate a pure mineral pixel waveform spectrum, and performing equalization processing to obtain an imaging mineral probability map; according to mineral content data obtained through core XRD total rock analysis, an imaging mineral spectrum is subjected to quantitative calibration, and distribution cut-off threshold values and pixel point value ranges corresponding to different minerals are recognized and deduced. The method can effectively solve the calculation error caused by the influence of the traditional imaging mineral calculation fluid on mineral calculation.

The invention discloses a rock physical forward modeling method applicable to formation pore fluid of carbon dioxide, and relates to the technical field of petroleum and natural gas engineering. The method comprises the steps of firstly obtaining a carbon dioxide physical property constraint condition based on a state equation of carbon dioxide under a reservoir temperature and pressure condition, and then based on the constraint condition and according to logging information of a target well, core analysis and a laboratory test result, carrying out formation evaluation to calculate reservoir parameters. Then, based on reservoir parameters, the sandstone content is obtained through calculation, a rock physical volume model of a target well is constructed, and finally, based on the model, corresponding rock physical forward modeling is conducted according to different carbon dioxide saturations by means of the equivalent medium theory to generate stratum elastic attribute parameters. And the change relation between the corresponding saturation and the stratum elastic attribute parameters is quantitatively represented, so that the CO2 quantitative monitoring precision and reliability can be remarkably improved by comprehensively considering the special physical properties of CO2, the fluid replacement mechanism and the seismic wave propagation characteristics.

The invention discloses an organic matter identification method based on seismic wave dispersion, and relates to the technical field of petroleum geophysical exploration, and the method comprises the steps: obtaining a target pre-stack seismic trace set and matched logging data, building an underground medium initial model based on the kerogen content and elastic response characteristics in the logging data, and obtaining an underground medium initial model; a to-be-inverted parameter matrix and a reflection coefficient weight matrix of an incident angle are calculated through a Shaw reflection coefficient calculation equation, frequency-division seismic wavelets are generated through the high sensitivity of organic matter to transverse wave dispersion, and a positive operator is constructed in combination with the wavelets and the reflection weight matrix. A shear wave velocity dispersion gradient which is highly sensitive to organic matters and weak in response to pore fluid is used as a main control inversion parameter, a combined recognition constraint term is constructed by combining a longitudinal wave velocity dispersion gradient and attenuation spectrum morphological characteristics, and a spatial optimal solution of a forward operator and a seismic trace set is calculated through a minimization objective function. And quantitatively associating the spatial optimal solution with the geophysical response characteristics of the organic matters to generate an organic matter spatial distribution diagram of the target reservoir.

The present invention discloses a high-gravity strong rainfall simulation device and a rainfall simulation method. The liquid inlet module is connected to the rainfall model. The liquid inlet module is used to supply the sprayed liquid to the soil model in the rainfall model box and can control the speed of the sprayed liquid. A viscous fluid is stored in the water supply tank, and the viscous fluid is used to simulate rainfall liquid and pore fluid; the method includes conducting a normal gravity rainfall simulation test to obtain a hydraulic pressure-rainfall intensity relationship curve when the rainfall liquid is the viscous fluid, and according to the similarity scale of the viscous fluid to simulate the high-gravity rainfall test, conducting a centrifugal rainfall simulation test under a high-gravity environment to obtain the transfer law between the rainfall intensity and the failure performance of the prototype soil sample. When the present invention uses a liquid with a viscosity coefficient higher than that of water as the rainfall simulation liquid, the effect of enhancing the rainfall intensity can be achieved in a high-gravity centrifugal test.

This invention relates to the field of experimental equipment technology, and particularly to an NMR combustion-explosion dynamic load multi-field coupling experimental device and method. The technical solution includes a control module, an impact module, a detection module, and a vibration reduction module; wherein, the control module includes an operating platform, a transmission line, an engine, a fuel tank, an oxygen tank, connecting pipes, a high-temperature resistant fuel nozzle, and a high-temperature and pressure resistant gas sealing pipe; the operating platform is located behind the engine. This invention achieves graded control of dynamic load through combustion-explosion-electromagnetic composite loading, integrates simultaneous detection of multiple physical fields such as nuclear magnetic resonance, acoustic waves, and resistivity, sets up multi-level vibration reduction and dissipation structures to absorb residual kinetic energy, adopts a high-temperature and high-pressure resistant sealing design to ensure safety, simulates ground temperature, ground stress, and pore fluid fields to reproduce the deep in-situ multi-field coupling environment, and is centrally controlled and automatically reset by the operating platform, thereby realizing a laboratory simulation of deep dynamic disasters with flexible and adjustable parameters.

The invention discloses a seismic reflected wave response high-fidelity forward modeling calculation method suitable for a deep saline water layer, and the method comprises the steps: S10, building a saline water layer pore fluid rock physical model according to the development characteristics of the saline water layer, and calculating the viscosity, density, longitudinal wave velocity and bulk modulus of the saline water layer pore fluid; s20, according to the development characteristics of the salt water layer, establishing a multi-scale rock physical model of the salt water layer to obtain an equivalent stiffness matrix of the salt water layer; s30, establishing a geology-earthquake forward modeling model; s40, calculating a salt water layer reflection and transmission coefficient matrix by using a propagation matrix method; and S50, calculating the reflected wave seismic response of the salt water layer. According to the method, seismic rock physical modeling and seismic forward modeling technologies are combined, the viscoelastic characteristic and the thickness of the salt water layer are considered, the actual geological condition is better met, the cost is low, the precision is high, the deep salt water layer seismic reflected wave response can be rapidly and accurately calculated, and theoretical support is provided for evaluation and optimization of the carbon storage space.

The present application relates to a method and system for determining the preservation effect of a sealed frozen core sample based on nuclear magnetic resonance re-saturation contrast, and belongs to the technical field of unconventional oil and gas exploration and development. The method comprises the following steps: first, obtaining and processing the sealed sample, performing a first T1-T2 two-dimensional nuclear magnetic resonance test after thawing, immediately performing re-saturation treatment, and immediately performing a second test after saturation; second, dividing each hydrogen-containing component fluid into regions and extracting signal amounts; third, calibrating the fluids of formation water, crude oil and dodecane, establishing a conversion relationship between oil-water hydrogen signal amounts and volumes, and then obtaining the oil-water volumes under sealed and re-saturated states; fourth, comparing the difference between the total fluid amount under the re-saturated state and the total fluid amount under the sealed state with the total fluid amount under the re-saturated state, and obtaining a ratio, which is defined as a re-saturation response coefficient, for quantitatively evaluating the preservation degree of the original pore fluid. The method can ensure the accuracy and reliability of the test results.

This invention provides a method for enhanced geological sequestration of carbon dioxide through self-emulsification. The method includes: establishing an injection well in a seafloor sedimentary layer; injecting a penicillin-based chemical agent and CO2 into the seafloor sedimentary layer through the injection well; the CO2 carrying the penicillin-based chemical agent and seawater fluid flowing within the sediments of the seafloor sedimentary layer, whereby the CO2 undergoes self-emulsification to form a water-in-water CO2 microemulsion; under the impetus of injection pressure and buoyancy, the mixed fluid containing the water-in-water CO2 microemulsion displaces pore seawater and diffuses within the seafloor sedimentary layer, achieving geological sequestration of carbon dioxide. This method, by injecting the penicillin-based chemical agent and CO2 into the target layer, enables the CO2 to undergo self-emulsification within the target seafloor layer, transforming the pore fluid into a water-in-water CO2 microemulsion with good dispersibility and stability, thereby improving displacement capacity and sweep range.

The application provides a shale pore fluid type and porosity determination method, device and medium. The method obtains nuclear magnetic resonance logging data of shale in a target interval, performs T2 spectrum component stripping processing on the data, obtains a plurality of corresponding nuclear magnetic resonance logging T2 sub-spectra, determines pore fluid type calibration characteristics according to differences in T1-T2 spectrum diagrams of shale with different clay mineral contents and under different core saturation states, calibrates the fluid type of the plurality of nuclear magnetic resonance logging T2 sub-spectra based on the pore fluid type calibration characteristics, obtains the fluid type corresponding to each nuclear magnetic resonance logging T2 sub-spectrum, and then determines the effective porosity and movable fluid porosity of the shale based on the plurality of nuclear magnetic resonance logging T2 sub-spectra and the corresponding fluid type. The method improves the calculation accuracy of the porosity, and provides a simple and reliable method for fluid type discrimination and porosity calculation of logging that only measures one-dimensional nuclear magnetic resonance logging and has no coring nuclear magnetic resonance experiment.

The application provides a method for exploiting natural gas hydrate and sealing carbon dioxide. The method comprises the following steps: injecting nitrogen into a natural gas hydrate reservoir of an area to be exploited, displacing reservoir pore fluid, making natural gas hydrate decompose to generate natural gas, collecting output fluid of a production well of the area to be exploited; detecting the composition of the output fluid, and when the natural gas content in the output fluid is less than a set value, stopping the injection of nitrogen, injecting carbon dioxide into the natural gas hydrate reservoir of the area to be exploited, forming carbon dioxide hydrate in a natural gas hydrate cavity, and displacing reservoir pore fluid, and collecting output fluid of the production well of the area to be exploited; the above steps can be repeated. The method provided by the application integrates natural gas hydrate exploitation and carbon dioxide sealing, and has the advantages of safety and reliability, wide action range, high working efficiency and the like.

The present invention discloses a method for monitoring the reservoir stability of an oil and gas depleted gas storage reservoir. The method includes a reservoir monitoring parameter measurement platform for the gas storage reservoir, an analysis module of the oil and gas field drilling platform server, and a reservoir stability evaluation module for the gas storage reservoir. The reservoir monitoring parameter measurement platform for the gas storage reservoir uploads a multi-modal device monitoring unit to collect and analyze data. The present invention collects relevant downhole information, calculates the Pearson correlation coefficient and analyzes the bidirectional coupling mechanical model for the collected downhole information. When the reservoir brittleness or pore fluid and its occurrence state exceed the preset reference stability coefficient, the reservoir stability of the gas storage reservoir is evaluated. When it does not exceed the preset reference stability coefficient, a bidirectional coupling mechanical model analysis is carried out on the changes of oil and gas fields with different depletion reasons, assisting oil and gas field engineers to timely discover local environmental changes and potential unstable factors caused by exploitation, providing a basis for engineers to optimize the exploitation link, improving the utilization efficiency of oil and gas field resources, and enhancing the safety of exploitation.

The invention provides a seismic wave dispersion and attenuation prediction method and related equipment, and relates to the field of geophysical fluctuation induced fluid flow. The method comprises the steps that based on the bubble vibration theory and a pore fluid seepage continuity equation, a target elastic modulus is obtained, and the target elastic modulus is an elastic modulus obtained after bubble vibration correction is added; fusing the target elastic modulus into a strain energy function of a classical pore acoustic elasticity theory to obtain the strain energy function; deducing to obtain a wave equation of the fluid saturated porous medium containing a small amount of bubbles under the action of pressure by combining the strain energy function, the kinetic energy function and the dissipated energy function; and solving the simplified wave equation through the plane wave to obtain the seismic wave speed and attenuation. According to the embodiment of the invention, the frequency dispersion and attenuation of seismic waves can be accurately predicted within a certain effective pressure range.

A workflow for data acquisition and processing to quantify immobile and producible fluids more accurately from log and core measurements is described. Also described are methods of reservoir characterization to distinguish producible from immovable fluids that use NMR measurements on core samples as endpoint references and calibration points for downhole logging. Endpoint signatures of pore fluids are easily identified by the NMR of core samples, thus providing more accurate results on formation fluid porosities and saturations from measured data.

The porous showerhead includes a porous top surface, a porous bottom surface, and a plurality of layers. The layers are stacked between the porous top surface and the porous bottom surface. The layers are arranged to be connected to a distribution plate of a showerhead assembly of a substrate processing system. An uppermost layer of the layers has the porous top surface. A bottommost layer of the layers has the porous bottom surface. Each of the layers contains particles that are partially melted to form pores. The pores of the layers satisfy at least one of lateral alignment with pores in one or more adjacent ones of the layers and fluid coupling with pores in one or more adjacent ones of the layers to provide extended pores. The extending pores extend from the porous top surface to the porous bottom surface.

This specification discloses a forward modeling method and apparatus for rock physics in time-lapse seismic monitoring. This involves determining an initial value S of the target fluid's saturation. G and change value ΔS G According to the initial value S G and change value ΔS G Determine the longitudinal wave velocity V in the target fluid; calculate the compressibility modulus M of the rock saturated with the pure target fluid based on the initial and varying values. G The saturated rock compressibility modulus M when the pore fluid does not contain the target fluid W Based on the compressibility modulus M of the rock saturated with the pure target fluid G The saturated rock compressibility modulus M when the pore fluid does not contain the target fluid W Calculate the compressibility modulus M of saturated rock after the target fluid saturation changes under high frequency conditions. ∞ Based on the compressibility modulus M of the saturated rock after the change in target fluid saturation under the aforementioned high-frequency conditions. ∞ The saturated rock compressibility modulus M after the target fluid saturation changes under the low-frequency conditions. F Calculate the attenuation model.

This invention proposes a corrosion-inhibiting polycarboxylate superplasticizer, its preparation method, and its application. The corrosion-inhibiting polycarboxylate superplasticizer is prepared by a ring-opening grafting reaction between an epoxy-containing polycarboxylate superplasticizer and triethanolamine borate. A functionalized framework is constructed using epoxy-containing monomers, and then corrosion-inhibiting groups are stably anchored to the molecular side chains through a nucleophilic ring-opening reaction, achieving molecular-level integration of water-reducing and corrosion-inhibiting functions. Through the directional adsorption of amino groups onto the surface of reinforcing steel to form a film, combined with the anodic passivation inhibition induced by borate, corrosive media are effectively isolated. Simultaneously, the released borate ions react with calcium ions in the pore fluid to form micro-precipitates in situ, filling capillary pores and significantly optimizing pore size distribution. This invention solves the problems of poor component compatibility and performance interference, significantly reducing the chloride ion permeability coefficient even at low dosages, and significantly improving the mechanical strength and durability of concrete. The process of this invention is simple, the reaction conditions are mild, and it is suitable for the protection of reinforced concrete structures in marine engineering and harsh environments.

The invention provides a shale pore fluid type and porosity determination method, equipment and a medium. According to the method, nuclear magnetic resonance logging data of shale in a target layer section are obtained, T2 spectrum component stripping treatment is carried out on the nuclear magnetic resonance logging data to obtain a plurality of corresponding nuclear magnetic resonance logging T2 sub-spectrums, pore fluid type calibration characteristics are determined according to the difference condition of T1-T2 spectrograms of shale with different clay mineral contents and in different rock core saturation states, and the pore fluid type calibration characteristics are determined according to the difference condition of the T1-T2 spectrograms of shale with different clay mineral contents. Performing fluid type calibration on the plurality of nuclear magnetic resonance logging T2 sub-spectrums on the basis of the pore fluid type calibration characteristics to obtain a fluid type corresponding to each nuclear magnetic resonance logging T2 sub-spectrum, and further determining the effective porosity and the movable fluid porosity of the shale on the basis of the plurality of nuclear magnetic resonance logging T2 sub-spectrums and the corresponding fluid types. According to the method, the calculation precision of the porosity is improved, and meanwhile, a simple, convenient and reliable method is provided for fluid type judgment and porosity calculation of well logging which only measures one-dimensional nuclear magnetic resonance well logging and does not have a coring nuclear magnetic resonance experiment.

The invention discloses a quasi-triaxial mud shale complex fracture conductivity testing device and method, and the device comprises a data monitoring and control system, and also comprises a quasi-triaxial stress loading system, a pore fluid saturation system, a temperature loading system, a fluid displacement system and a strain testing system which are respectively connected with the data monitoring and control system. A complex crack simulation system is arranged in the quasi-triaxial stress loading system; the quasi-triaxial stress loading system is respectively connected with the pore fluid saturation system, the temperature loading system, the fluid displacement system and the strain testing system. According to the method, the mud shale complex fracture flow conductivity damage rule under different geological conditions, different displacement fluid parameters and different stress conditions can be obtained, the optimal flow conductivity matching process scheme is formed, and reference is provided for optimizing the fracture structure and improving the fracturing construction process.

The invention relates to the technical field of electro-osmosis reinforcement of soft clay, and discloses an electro-osmosis model test system for realizing multi-parameter monitoring, the electro-osmosis model test system comprises a bottom plate, a base and a mounting cylinder, the bottom plate is arranged below the base; a containing chamber is arranged at the top in the base, and a drainage collecting chamber is arranged at the bottom in the base; the bottom of the mounting cylinder is embedded in the containing chamber, a soil sample layer is contained in the mounting cylinder, an anode and a cathode are arranged on the upper side and the lower side of the soil sample layer respectively, a layer of porous stone and filter paper is arranged on one side, far away from the soil sample layer, of each of the anode and the cathode, a plurality of reserved holes are formed in the side wall of the mounting cylinder at intervals, and the reserved holes are communicated with the soil sample layer. And a potential probe is arranged at each preformed hole. The problems that a traditional electroosmosis model test system is single in monitoring parameter, low in precision, rough in structure and the like are solved, particularly, soil deformation can be monitored, and sufficient collection of pore liquid is achieved.

The invention particularly relates to a modeling and frequency response calculation method based on acoustic impedance characteristics of submarine sediments. The method comprises the following steps: firstly, acquiring basic physical parameters such as mineral composition, porosity, solid particle volume modulus, pore fluid volume modulus and density of the sediments; then carrying out weighted average on the multi-mineral components, and calculating to obtain an equivalent bulk modulus of the solid skeleton; further determining a low-frequency limit volume modulus and a high-frequency limit volume modulus by combining a Biot theory and a fluid-solid coupling acoustic model; on the basis, a frequency-dependent effective volume modulus expression is constructed, and the equivalent acoustic impedance under different frequencies is calculated according to the frequency-dependent effective volume modulus expression. According to the method, the influence of the multi-mineral composition of the sediment and the property of the pore fluid can be considered at the same time, and the frequency dependence characteristic is introduced, so that accurate modeling of the equivalent acoustic impedance of the seabed sediment is realized, and the method has the advantages of high theoretical accuracy, wide application range and high engineering realizability.

The invention provides a fracturing construction parameter coupled fracturing performance evaluation method, which comprises the following steps: determining evaluation factors influencing the fracturing performance of a target reservoir, the evaluation factors comprising rock brittleness, crustal stress parameters, fracture toughness and net pressure; respectively calculating to obtain a weight value of each evaluation factor; and based on the evaluation factors and the weight value of each evaluation factor, in combination with a fracturing evaluation model, calculating to obtain the fracturing index of the target reservoir. The invention overcomes the defect that the comprehensive influence of net pressure influenced by construction parameters is not considered in the prior art, and provides a fracturing property evaluation model which comprehensively considers the elastic parameters of comprehensive characteristics such as reservoir rock composition, structure, pore, fluid and the like.

The present invention belongs to the technical field of rock physical property testing, and discloses a method for calculating the water saturation of rocks, which includes: obtaining a plug sample and a powder sample; measuring the rock frame modulus of the powder sample, drying the plug sample, performing water inlet treatment until it is water-saturated, and recording its density, Young's modulus and Poisson's ratio under different water-containing states; calculating the longitudinal and transverse wave velocities of the plug sample under different water-containing states accordingly, and further obtaining the longitudinal wave velocity of the pore fluid. At the same time, combining the rock frame modulus data, calculating the bulk modulus of the pore fluid of the plug sample; calculating the pore fluid saturation data of the sample under different water-containing states according to the longitudinal wave velocity and bulk modulus data of the pore fluid. The technical solution of the present invention has strong operability, accurate calculation of water saturation, low cost, and can more conveniently provide reliable water saturation information of water-rich rock masses for the prevention and control evaluation of coal mine water disasters.

The application discloses a kind of suitable for deep brackish aquifer seismic reflection wave response high fidelity simulation calculation method, the method includes S10: according to brackish aquifer development characteristics, establish brackish aquifer pore fluid rock physics model, calculate the viscosity, density, longitudinal wave velocity and bulk modulus of brackish aquifer pore fluid;S20: according to brackish aquifer development characteristics, establish brackish aquifer multi-scale rock physics model, obtain brackish aquifer equivalent stiffness matrix;S30: establish geology-seismic forward modeling;S40: utilize propagation matrix method to calculate brackish aquifer reflection and transmission coefficient matrix;S50: calculate brackish aquifer reflection wave seismic response.The application combines seismic rock physics modeling and seismic forward simulation technology, considers the viscoelasticity characteristics and thickness of brackish aquifer, is more in line with actual geological conditions, low in cost, high in accuracy, can quickly and accurately calculate deep brackish aquifer seismic reflection wave response, provides theoretical support for the evaluation and optimization of carbon storage space.

The invention relates to a core pore fluid component identification and quantitative analysis method based on two-dimensional nuclear magnetic resonance, and belongs to the technical field of core analysis. The method comprises the following steps: acquiring core two-dimensional nuclear magnetic resonance spectrogram data; constructing a relaxation time matrix and a signal intensity matrix; calculating a relaxation time ratio matrix; based on a transverse relaxation time boundary and a ratio boundary, mapping the signal to nine fluid components such as clay bound water and adsorbed oil through a classification function; and quantizing the signal intensity of each component by using a Kronecker function, and finally calculating the relative content of each component. According to the method, fluid relaxation characteristic distribution of the T-Tspectrogram is covered by a seamlessly connected polygonal region, so that a signal blind area of a circular plate is eliminated, in-situ quantitative analysis of multi-component fluid in full-scale pores is realized, and high-precision data support is provided for oil and gas reservoir evaluation and development scheme formulation.