37 results about "Transverse Relaxation Time" patented technology

This invention discloses a method and system for testing rock pore size distribution curves based on nuclear magnetic resonance (NMR) technology. The method includes: preprocessing the rock sample to be tested and obtaining the porosity and transverse relaxation time curves of the sample at room temperature and low temperature; obtaining the measured value of unfrozen water content by the ratio of low-temperature to room-temperature porosity, serving as an objective benchmark for verifying theoretical results; converting the room-temperature relaxation curve into a cumulative pore size distribution curve, fitting and extracting pore characteristic parameters, and substituting relevant characteristic parameters into a theoretical model to calculate the theoretical value of unfrozen water content; iteratively optimizing the transverse surface relaxation rate to ensure the deviation between the theoretical and measured values ​​meets accuracy requirements; establishing a precise correspondence between relaxation time and pore radius; and outputting the final pore size distribution curve. Each step is interconnected and mutually supportive, forming a complete logical closed loop. This provides reliable technical support for characterizing rock pore structure.

This disclosure provides a nuclear magnetic resonance (NMR) analysis method for establishing the chemical composition and condensed-state structure of fluorine-containing materials and its application. The method includes: placing fluorine-containing materials under different operating conditions in a single-sided NMR spectrometer; under a single-sided inhomogeneous magnetic field environment; presetting parameters for a spin echo pulse sequence; using the spin echo pulse sequence to excite fluorine and hydrogen nuclei in the fluorine-containing material to obtain coupled NMR signals of fluorine and hydrogen nuclei; determining echo peak data from the coupled NMR signals according to the preset parameters; processing the echo peak data according to the structural characteristics of the fluorine-containing material to obtain relaxation spectrum fingerprint data; performing data transformation on the relaxation spectrum fingerprint data to obtain transverse relaxation time data; and establishing a relaxation spectrum fingerprint database and a transverse relaxation time database of the coupling of fluorine and hydrogen nuclei in the fluorine-containing material based on the relaxation spectrum fingerprint data and transverse relaxation time data under different operating conditions.

The invention provides a method and a system for determining diamond nitrogen vacancy color center intrinsic transverse relaxation time. The method comprises the following steps: acquiring a transverse relaxation time calibration value of a standard nitrogen vacancy color center diamond sample; respectively measuring the first transverse relaxation time and the second transverse relaxation time of the standard nitrogen vacancy color center diamond sample and the nitrogen vacancy color center diamond sample to be detected under the action of the non-uniform external magnetic field on the detection platform; according to the transverse relaxation time calibration value and the first transverse relaxation time, calculating the transverse relaxation time deviation of the standard nitrogen vacancy color center diamond sample under the action of the non-uniform external magnetic field; and according to the transverse relaxation time deviation and the second transverse relaxation time, calculating the intrinsic transverse relaxation time of the nitrogen vacancy color center diamond sample to be measured. According to the method and the system, an ultrahigh-uniformity static magnetic field environment with extremely high cost is not needed, the detection method is high in robustness, and the calibration accuracy of the to-be-detected sample in a complex or non-ideal experimental environment can be remarkably improved.

The invention discloses a low-field NMR relaxation time rapid measurement method, and the method comprises the steps: designing an IR-bSSFP pulse sequence which comprises a 180-degree reversal pulse and an excitation pulse sequence, and enabling the flip angle of a radio frequency excitation pulse in the excitation pulse sequence to be a pseudo-random flip angle; the radio-frequency phases of the adjacent radio-frequency excitation pulses are linearly changed by a fixed phase increment; based on the IR-bSSFP pulse sequence, obtaining a component MRF signal sequence of a measured object, and simulating a magnetization vector evolution process to obtain a dictionary matrix; matching the component MRF signal with a dictionary matrix pattern in combination with a smooth constraint term to obtain corresponding longitudinal relaxation time and transverse relaxation time; the invention also discloses low-field NMR relaxation time rapid measurement equipment, which comprises a pulse sequence construction module, a dictionary generation module and a mode matching module. Multi-parameter information can be obtained through single scanning, the measurement time is remarkably shortened, the experiment complexity is reduced, and the precision and repeatability of a measurement result are improved.

The invention relates to the technical field of rock physical analysis in oil-gas exploration and development, and particularly provides a shale full-size pore structure characterization method which comprises the following steps: acquiring high-pressure mercury injection experimental data and nuclear magnetic resonance experimental data of a shale sample, dividing a pore system of the shale sample into a small pore section and a large pore section by an inflection point of fractal dimension, respectively fitting the pore throat radius of the small pore section and the pore throat radius of the large pore section with the transverse relaxation time to obtain two groups of conversion coefficients, respectively inverting the pore diameter distribution curve of the small pore section and the pore diameter distribution curve of the large pore section by utilizing the two groups of conversion coefficients, and carrying out segmented integration according to the intersection point of the two curves to characterize the full pore diameter distribution of the shale sample. According to the method, a fractal inflection point division pore system is introduced, deep structure information is excavated by utilizing a fractal theory, segmentation fitting is carried out, and the technical problems that a traditional HPMI-NMR conjoint analysis method is insufficient in precision under the conditions of large displacement pressure, low mercury injection saturation and strong heterogeneity are solved.

The invention relates to the technical field of geological exploration, in particular to a dessert interval determination method and device, a storage medium and a computer program.The method comprises the steps that distribution information of one-dimensional nuclear magnetic transverse relaxation time T2 and distribution information of longitudinal relaxation time T1 of rock samples of different depths of a continental facies shale oil and gas reservoir are obtained, sorting the distribution information of the transverse relaxation time T2 and the distribution information of the longitudinal relaxation time T1 of each rock sample along the corresponding depth of each rock sample to obtain pore size distribution information and oil-water distribution information of the continental facies shale oil and gas reservoir; and determining the sweet spot interval of the continental facies shale oil and gas reservoir according to the pore size distribution information and the oil-water distribution information. According to the method and the device, the oil content conditions of the reservoirs can be compared more visually, and the dividing efficiency and accuracy of the dessert layer sections are improved.

A method for generating a property representation of a substance is described. The method comprises: obtaining portions of one or more nuclear magnetic resonance (NMR) data of the substance, where each NMR data portion comprises one or more NMR datasets, each NMR dataset comprising intensity data and relaxation data; processing each NMR data portion into a multi-dimensional distribution of a fitting data set by performing a plurality of fits of a function, where the function includes at least 3 fitting parameters; and generating a characteristic representation of the substance from the fitting data set. The processing includes applying at least one initial guess value. Each set of fitting data comprises data embedded with at least one subset of fitting data comprising an apparent longitudinal relaxation time (T1 *), an associated apparent transverse relaxation time (T2 *) and an associated intensity (M0), preferably said function being a function of a model representing the obtained NMR data portion.

This invention provides a silica sol and polishing composition that has a large amount of water trapped on the surface of silica particles, can maintain this state of trapped water even under high-temperature conditions, and exhibits high dispersion stability even when the temperature is increased. [Solution] A silica sol containing silica particles, wherein the transverse relaxation time of nuclide 1H at a temperature of 25°C, as measured by the CPMG method using a pulsed NMR spectrometer, is 400 ms or less, and the temperature dependence of the transverse relaxation time obtained by subtracting the transverse relaxation time at 25°C from the transverse relaxation time at 40°C is less than 100 ms.

The application discloses a kind of based on diagenetic facies classification nuclear magnetic logging inversion granularity parameter method, comprising the following steps: S1: carry out nuclear magnetic resonance and granularity analysis test experiment, obtain saturated water T2 spectrum cumulative curve and granularity cumulative curve;S2: draw transverse relaxation time T2-particle size relationship curve, scale range division is carried out to particle size, obtain the relationship formula one of transverse relaxation time T2 and particle size under each scale range;S3: the diagenetic lithofacies type of target area is divided;S4: with diagenetic lithofacies type as constraint, relationship formula one is optimized, and the relationship formula two of transverse relaxation time T2 and particle size under different diagenetic lithofacies types and different scale ranges is obtained;Establish the standard of logging curve identification diagenetic lithofacies;S5: obtain the logging curve of target wellbore profile, identify the diagenetic lithofacies of target wellbore profile, and obtain the continuous granularity parameter of target wellbore profile by inversion in combination with relationship formula two.The present application can quantitatively invert the particle size distribution on wellbore profile by nuclear magnetic logging.

The application provides a shale oil reservoir pore structure correction method, device, equipment and medium; relates to the pore structure correction technical field, and the method comprises the steps of: carrying out nuclear magnetic resonance test on the first shale to obtain one-dimensional nuclear magnetic T2 spectrum and two-dimensional nuclear magnetic T1-T2 spectrum of the first shale; T1 represents longitudinal relaxation time, and T2 represents transverse relaxation time; identifying the one-dimensional nuclear magnetic T2 spectrum to obtain the first signal amplitude of the first shale; identifying the two-dimensional nuclear magnetic T1-T2 spectrum to obtain the second signal amplitude of the first shale; the correlation between the first signal amplitude and the second signal amplitude is established; the correlation is used to determine the amplitude conversion relationship of the one-dimensional nuclear magnetic T2 spectrum and the two-dimensional nuclear magnetic T1-T2 spectrum corresponding to the skeleton signal of the first shale; based on the amplitude conversion relationship, the one-dimensional nuclear magnetic T2 spectrum and the two-dimensional nuclear magnetic T1-T2 spectrum of the target shale under the saturated state, the pore structure of the target shale to be corrected is corrected. In this way, the nuclear magnetic porosity and pore size distribution of the shale oil reservoir can be accurately determined.

The invention provides a compact glutenite reservoir classification method, a compact glutenite reservoir classification device, a medium and a product. The compact glutenite reservoir classification method comprises the following steps: acquiring a plurality of transverse relaxation time spectrum curves of a to-be-classified reservoir; classifying the plurality of transverse relaxation time spectrum curves to obtain a plurality of curve types and a plurality of classified transverse relaxation time spectrum curves corresponding to each curve type; determining a conversion relation between the corresponding relaxation time and the pore throat radius according to the plurality of classified transverse relaxation time spectrum curves; determining a multi-component index corresponding to the curve type according to the plurality of classified transverse relaxation time spectrum curves and a conversion relation between the relaxation time and the pore throat radius; calculating a movable fluid aperture ratio, a classification coefficient and reservoir permeability corresponding to the curve type; determining an identification standard of the reservoir type corresponding to the curve type according to the aperture ratio of the movable fluid, the classification coefficient, the reservoir permeability and the multi-component index; and according to the identification standard, the reservoir classification of the to-be-classified reservoir is determined, and the calculation precision of the compact glutenite reservoir is improved.

The application discloses a method and device for determining a full-size distribution curve of rock pore radius, and the method comprises the following steps: obtaining a rock sample, pretreating the rock sample to obtain a standard core, wherein the pretreatment at least comprises oil washing treatment and / or drying treatment; determining gas-measured pore information of the standard core, and obtaining core scanning data of the standard core through a computer tomography device; treating the standard core into a saturated water core, and obtaining a transverse relaxation time spectrum of the saturated water core through a magnetic resonance device; and determining a rock pore radius distribution curve corresponding to the rock sample according to the core scanning data, the gas-measured pore information and the transverse relaxation time spectrum. The method not only improves the accuracy and reliability of pore structure analysis, but also provides a scientific basis for optimizing water flooding schemes and improving the producing degree of crude oil in micro pores.

This invention provides a method, system, device, and storage medium for predicting sandstone permeability. The method includes: acquiring a first or second permeability prediction model; acquiring the geometric mean of the pore radius or the NMR T2 distribution within the range of transverse relaxation time >40ms corresponding to a cumulative mercury saturation of 20% for the target sample, as well as the cumulative mercury saturation distribution of the high-pressure mercury intrusion pore size or the cumulative percentage distribution of the NMR pore size; acquiring the lower limit of the pore size of the movable fluid storage space of the target sample and using it as the boundary point for fractal analysis; combining the aforementioned cumulative mercury saturation distribution of the high-pressure mercury intrusion pore size or the cumulative percentage distribution of the NMR pore size to determine the first or second fractal dimension of the target sample; determining the permeability of the target sample using the first permeability prediction model based on the aforementioned pore radius and first fractal dimension, or determining the permeability of the target sample using the second permeability prediction model based on the aforementioned geometric mean and second fractal dimension.

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.

This invention discloses a nuclear magnetic resonance (NMR) method for measuring the solid phase deposition of crude oil in porous media, belonging to the field of oil and gas reservoir development technology. By using a single saturation of crude oil in a core sample and leveraging the characteristics of online NMR technology, the method employs a comparison of experimental and NMR measurements, along with a 1:1 standard line reference, to determine the standard echo interval T in the transverse relaxation time T2 measurement acquisition parameters. E This method directly measures the amount of solid phase deposition in pore fluids in situ, solving the technical problems of existing technologies that cannot maintain the original characteristics of the sample, effectively avoid the interference of solid skeleton response and solid phase deposition particles, and are difficult to measure the solid phase deposition content of active oil in situ. It achieves the technical effect of rapid, efficient and accurate measurement of the amount of crude oil solid phase precipitation in cores under specific temperature and pressure conditions. The method is reliable in principle, simple to operate and highly applicable, and the test results are accurate and reliable, making it more suitable for the fine characterization needs of complex oil and gas reservoirs.

The invention relates to a method of MR imaging of an object, namely of at least a part of the female breast. The method of the invention comprises the steps of: a) subjecting the object (10) to an imaging sequence comprising RF excitation pulses and switched magnetic field gradients, wherein multiple echo signals are generated at different echo times (TE1, TE2, TE3) after each RF excitation pulse, b) acquiring the echo signals along a set of radial or spiral k-space trajectories covering a given k-space region, wherein each of the echo signals generated after an RF excitation pulse is assigned a different orientation of the radial or spiral trajectory in k-space; c) reconstructing a single echo image for each echo time (TE1, TE2, TE3) from the echo signals acquired; d) deriving high-resolution water, fat, B0 and / or apparent transverse relaxation time (T2*) maps from the single echo images using a deep learning algorithm; and d) synthesizing a high-resolution mammogram from the water, fat, B0 and / or T2* maps. Moreover, the invention relates to an MR device (1) and to a computer program for an MR device (1).

A toner comprising a toner particle comprising an organic pigment and a binder resin, wherein, in a solid-state NMR measurement at 60° C. using a solid fraction obtained by specific procedure for dissolving the toner in chloroform as a sample, a transverse relaxation time T2 of a peak observed between 1.5 and 2.5 ppm is from 0.08 to 0.13 ms.

The invention discloses a method for measuring different-scale pore rebound coefficients of shale based on a pressure-pressure low-field nuclear magnetic resonance experiment, and relates to the technical field of shale reservoir physical property measurement, which comprises the following steps: carrying out low-field nuclear magnetic resonance measurement on a saturated water shale sample under different confining pressures; obtaining a nuclear magnetic resonance transverse relaxation time spectrogram of the saturated water shale sample under different confining pressures and the area of each spectrum peak in the spectrogram; acquiring a pore size distribution curve graph of the saturated water shale sample according to the area of each spectral peak in the spectrogram and the relationship between the transverse relaxation time and the pore size; and based on the area of each spectral peak in the spectrogram, calculating a total pore average pore rebound coefficient and pore rebound coefficients of different scales in combination with a pore rebound coefficient conversion formula. The method can be used for rapidly, nondestructively and finely measuring the pore rebound coefficient of the shale, and is simple and convenient to operate.

The invention relates to a hybrid insulator bonding interface strength prediction device and method based on nuclear magnetic resonance. The prediction device comprises a nuclear magnetic resonance sensor; the nuclear magnetic resonance sensor comprises a cylindrical permanent magnet, a ferromagnetic base and a radio frequency unit, the ferromagnetic base is arranged at one end of the cylindrical permanent magnet, and the radio frequency unit is arranged at the end, away from the ferromagnetic base, of the cylindrical permanent magnet; the measuring method comprises the following steps: scanning the bonding interface of the insulating part of the hybrid insulator and the silicon rubber coating layer; determining the transverse relaxation time by using a CPMG pulse sequence; by arranging the nuclear magnetic resonance sensor, the nuclear magnetic resonance sensor utilizes the nuclear magnetic resonance phenomenon to detect the bonding interface of the insulating part of the hybrid insulator and the silicon rubber coating layer, accurate prediction can be carried out in various complex environments, and meanwhile, aging of the bonding interface of the hybrid insulator under the influence of the natural environment can be detected; the measurement accuracy is improved; in addition, the prediction device is small in size and is not limited by special large instruments and environments.

The invention provides a transverse relaxation time spectrum correction method and device of crude oil, equipment and a medium, and relates to the technical field of reservoir detection. The method comprises the following steps: obtaining an average conversion coefficient of a saturated target oil core according to transverse relaxation time spectrums of target oil under a bulk phase condition and a core pore condition and core pore diameter distribution of the saturated target oil core; obtaining a first correction factor according to the average conversion coefficients of the saturated light oil core and the saturated simulated oil core; establishing a correlation equation between the first correction factor and the heavy component distribution of the saturated simulated oil core, and obtaining a second correction factor in combination with the heavy component distribution of the saturated stratum crude oil core; and obtaining the corrected transverse relaxation time spectrum of the saturated formation crude oil rock core according to the second correction factor. According to the method provided by the invention, the deviation of the transverse relaxation time spectrum caused by the limited flow of the heavy component is corrected, and the quantification accuracy of the production law of the crude oil in the small pores is improved.

This invention discloses a rapid prediction system for crude oil SARA composition based on low-field nuclear magnetic resonance (NMR), relating to the fields of petrochemical analysis and energy resource development. The system workflow is as follows: Samples covering light, medium, heavy, and high-asphalt crude oil are prepared and placed in tubes; LF-NMR transverse relaxation time (T₂) spectra are acquired using CPMG sequences, and experimental parameters are standardized; the spectra are preprocessed, including normalization and noise reduction, and features are extracted; a partial least squares regression (PLSR) model is constructed using column chromatography measurements as a reference, and optimized through cross-validation and external validation; LF-NMR data of unknown samples are input, and the system rapidly outputs the contents of saturated hydrocarbons, aromatic hydrocarbons, resins, and asphaltenes. This system requires only 5-10 minutes for a single analysis, has a prediction R² exceeding 0.95, is adaptable to crude oils with different API strengths and viscosities, has no solvent contamination, can be deployed on-site, and is suitable for oilfield development, refining optimization, and crude oil grading and pricing scenarios.

This invention discloses a method, apparatus, device, and storage medium for determining shale relaxation time, comprising: simulating a pre-defined molecular simulation model in a pre-set experimental simulation environment to obtain the inter-pair distance and inter-pair angle of hydrogen proton pairs in the molecular simulation model; obtaining the residual dipole coupling relaxation time based on the inter-pair distance and inter-pair angle; and obtaining the transverse relaxation time based on the residual dipole coupling relaxation time and the theoretical relaxation time. The shale relaxation time determination method, apparatus, device, and storage medium disclosed in this application solve the problem of uncertainty or significant mismatch between the pore size distribution derived from the transverse relaxation time based on NMR theory and the actual pore size distribution. This allows for a more accurate reflection of the actual pore size distribution through the calculation of the residual dipole coupling relaxation time under nano-constraint effects, thereby ensuring the accuracy of shale oil reservoir evaluation.

FIELD: mining.SUBSTANCE: group of inventions relates to means for determining gas content in a methane reservoir in deep coal seams. When implementing the method for determining the gas content in a methane reservoir in deep coal seams, a base spectrum of the transverse relaxation time of a dried sample of reservoir rock, spectra of the transverse relaxation time before the establishment of adsorption equilibrium at various pressures and spectra of the transverse relaxation time after the establishment of adsorption equilibrium at various pressures are obtained. Based on the transverse relaxation time spectra before the adsorption equilibrium is established at different pressures and the transverse relaxation time spectra after the adsorption equilibrium is established at different pressures, the free gas signals are determined at different pressures. Based on the base transverse relaxation time spectrum, transverse relaxation time spectra before adsorption equilibrium is established at different pressures, and free gas signals at different pressures, the adsorbed gas signals are determined at different pressures. Based on the base transverse relaxation time spectrum, adsorbed gas signals at different pressures, and transverse relaxation time spectra after adsorption equilibrium has been established at different pressures, corrected transverse relaxation time spectra after adsorption equilibrium has been established at different pressures are determined. Based on the free gas signals at different pressures and the corrected transverse relaxation time spectra after establishing adsorption equilibrium at different pressures, the actual free gas content at different pressures is obtained. Based on the base transverse relaxation time spectrum, free gas signals at different pressures and corrected transverse relaxation time spectra after establishing adsorption equilibrium at different pressures, the actual content of adsorbed gas at different pressures is obtained. Based on the actual content of free gas and the actual content of adsorbed gas at different pressures, a model for determining the gas content is constructed. The dried rock mass from the deep coal seam methane reservoir under test and the pressure in the deep coal seam methane reservoir are obtained. This rock mass from the deep coal seam methane reservoir under test and the pressure in the deep coal seam methane reservoir as input values for the gas content determination model are used to obtain the methane content of the deep coal seam methane reservoir under test.EFFECT: increasing the accuracy of determining gas content in a methane reservoir in deep coal seams.4 cl, 12 dwg

The application discloses a kind of high-temperature baked food vacuum cooling process in the prediction method of moisture migration, method is: to high-temperature baked food sample Establishing porous medium model, the temperature, moisture content and pressure data of sample are predicted;Sample is placed in the vacuum cavity of vacuum cooling device, set vacuum cooling working condition parameter, start and begin vacuum cooling, and obtain pressure, temperature and moisture content data by collection;In the process of sample vacuum cooling, the transverse relaxation time T2 spectrum of sample in the process of vacuum cooling is collected using nuclear magnetic resonance moisture meter;According to the relationship between moisture content and T2 relaxation spectrum in the process of vacuum cooling Peak area, the function model of moisture content change in the process of vacuum cooling is obtained by fitting function;Verify porous medium model.The application can predict the moisture migration of high-temperature baked food in the process of vacuum cooling by establishing porous medium model, and is verified by vacuum cooling device, to avoid the subjectivity and tediousness of experiment.

The invention discloses a microfluidic-combined magnetic relaxation veterinary drug residue detection method which comprises the following steps: selecting and preparing a standard solution containing a veterinary drug standard substance, and then preparing a magnetic nanoparticle solution of a coupling antibody antigen corresponding to the standard solution; carrying out magnetic separation on the mixed solution of the three solutions by using a magnetic block, and separating out an antibody magnetic bead solution combined with a target object; after the separated antibody magnetic bead solution combined with the target object flows into a detection cavity, the detection cavity is placed in a uniform magnetic field environment with a magnetic field main direction, a CPMG radio frequency pulse sequence is transmitted to a coil, and the transverse relaxation time of a sample solution is obtained through treatment; the uniform magnetic field environment is passive shimming; and veterinary drug residue detection is carried out according to the transverse relaxation time. According to the invention, the time of magnetic separation is optimized, a reaction system and time parameter optimization oriented to a microfluidic environment are determined, and sample detection is executed and completed at a minimum dosage and a fastest speed.

A method of imaging a biological material having a component that exhibits an ultra-short transverse relaxation time after excitement by electromagnetic energy is disclosed. More specifically, balanced steady state free precession ultra-short echo time (bSSFP UTE) magnetic resonance imaging (MRI) is used in combination with 3D center-out trajectory data collection and image subtraction techniques, to yield accurate high spatial resolution images of a material component having an ultra-short transverse relaxation time. In an embodiment, the 3D center-out trajectory can be a 3D rosette k-space trajectory. The disclosed methods can be used to image, among other things, biological materials such as without limitation, cortical and trabecular bones, lung parenchyma, tendons, and ligaments. In a particular example, the disclosed methods are used to image the myelin bilayer in brain white matter, such as for example, to detect, treat, or monitor brain lesions in multiple sclerosis patients.

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 invention discloses a reservoir pore structure full-scale characterization method and device based on cumulative fractal, equipment and a medium, and relates to the technical field of computers. Comprising the following steps: acquiring multi-source measurement data of a to-be-measured rock sample; correcting the high-pressure mercury injection experimental data by utilizing the pore geometric information of macropores in the rock sample to be measured so as to construct a capillary pressure-saturation curve; a cumulative fractal equation is established, and a fractal dimension spectrum is obtained through inversion solution by using a preset algorithm; performing variable exponential conversion on the nuclear magnetic resonance transverse relaxation time T2 spectrum data based on a nonlinear mapping relation by using a fractal dimension spectrum to obtain a full-scale aperture distribution curve; and carrying out data fusion on the three-dimensional pore topology network structure parameters extracted based on CT scanning image data, the multi-dimensional fractal geometric features and the full-scale pore size distribution curve so as to construct a comprehensive representation model. Therefore, multi-source information can be organically fused, and full-scale accurate characterization of continuous heterogeneity of the reservoir pore structure is realized.

The application provides a fluid distribution and oil layer interpretation method based on nuclear magnetic frequency division processing, and belongs to the technical field of tight oil and gas exploration and development. The application detects 1D / 2D nuclear magnetic spectrum of a sample in the saturated oil, saturated water, saturated oil centrifugation and saturated water centrifugation states, determines the distribution characteristics of different property fluids on the transverse relaxation time, carries out twice frequency division processing on the nuclear magnetic logging T2 spectrum through the nuclear magnetic frequency division processing, obtains the content of different property fluids through the peak area proportion of the four sub-spectra, identifies different state fluids of the reservoir according to the form of the nuclear magnetic T2 spectrum, and finally evaluates and classifies the oil layer based on the nuclear magnetic frequency division processing result. The application can quantitatively identify different property fluids of the reservoir existing in different pores, can more effectively and accurately divide the fluid property of the reservoir, and greatly improves the oil layer identification precision.

The invention provides a method and device for measuring the minimum miscible pressure of CO2 and crude oil and electronic equipment, and belongs to the technical field of miscible pressure determination.The method comprises the steps that the transverse relaxation time of CO2 and crude oil which are dissolved and balanced at the same temperature and under different pressures is obtained, and the transverse relaxation time is obtained through detection with the nuclear magnetic resonance technology; calculating the logarithmic mean value of the transverse relaxation time, and constructing a curvilinear relation graph of the logarithmic mean value of the transverse relaxation time along with the change of the pressure; and determining the minimum miscible pressure of CO2 and crude oil based on the curvilinear relationship graph. According to the scheme, the minimum miscible pressure of the CO2 and the crude oil is measured by using the nuclear magnetic resonance technology, so that the measurement cost of the minimum miscible pressure of the CO2 and the crude oil can be reduced, the measurement efficiency is improved, and the method has relatively high usability and practicability.