376 results about "Petroleum exploration" patented technology

The invention relates to the field of oil exploration, and particularly discloses a karst area oil exploration target optimization and resource quantity prediction method based on three-dimensional geological modeling. The method comprises the steps that firstly, seismic data, logging data and a rock core analysis result of a karst area are collected, data normalization and time-depth conversion are carried out, and a three-dimensional geologic model fusing structural constraints and physical property constraints is constructed; then multi-attribute indexes such as a coherent body, curvature, amplitude attenuation, deep lateral resistivity and interval transit time are selected, and karst development indexes are calculated through principal component analysis; in combination with parameters such as reservoir thickness, porosity, permeability, trap integrity and oil and gas display, utilizing a multi-index weighted scoring method to screen exploration favorable blocks; and finally, calculating reserves according to a volumetric method to obtain resource quantity prediction results of different target areas. According to the method, three-dimensional fusion modeling, multi-index quantitative optimization and chained calculation of multi-source data are realized, and quantifiable and traceable technical support is provided for oil exploration deployment in a karst area.

The invention discloses a formation collapse pressure prediction method based on a feature marking physical information neural network, and relates to the technical field of oil exploration and development. The method comprises the following steps: collecting multi-scale data of logging, earthquakes, cores and the like, and constructing a physical constraint framework in combination with a well track stress field model; a data enhancement module combining expert knowledge and a Beta distribution mixed strategy is utilized to carry out interpolation on missing values and generate an enhanced data set conforming to geological laws; a multi-head self-attention encoder comprising a feature word segmentation device and a Transform is constructed, original parameters are converted into embedded vectors, and deep interaction features are mined; a physical consistency measurement function based on a collapse pressure mechanism is introduced, and a total loss function containing data loss and physical loss is constructed for joint optimization. According to the method, the problem of geological sample scarcity is effectively solved, it is ensured that the prediction result meets the rock mechanics equilibrium condition, and the prediction precision and robustness of the complex formation collapse pressure are remarkably improved.

The invention discloses a horizontal well while-drilling method and system suitable for ultra-deep oil and gas reservoir development, and belongs to the technical field of oil exploration and development. (2) accurate target entering is guaranteed through a marker bed control method and a stable inclination top detection method; and 3) predicting the position of the drill bit after target entering to guide the adjustment of the horizontal well. The horizontal well track is adjusted in real time by measuring stratigraphic layering and well deviation data during drilling, the drilling rate of a reservoir can be effectively increased, and an effective technical means can be provided for efficient development of deep oil and gas reservoirs.

The invention relates to an oil-containing rock sample batch freezing device, an analysis system and an analysis method, and relates to the technical field of oil exploration. A plurality of samples can be placed on the sample plate provided with the plurality of sample cavities at a time, and the sample plate can be quickly frozen by introducing the refrigerating fluid into the first flow channel in the sample plate, so that low-temperature storage of all the samples is realized. The heat preservation box is of a split structure, the heat preservation box is kept in a closed state when the samples do not need to be taken, and the heat preservation box is temporarily opened under the action of the driving mechanism when the samples need to be taken, so that the samples are always in a low-temperature state, and the analysis result is prevented from being influenced by loss of light hydrocarbon components. The oil-containing rock sample batch freezing device is arranged on the pyrolysis instrument, the manipulator of the pyrolysis instrument can grab samples in the sample cavity nearby and send the samples to the detection mechanism for analysis, the time for exposing the samples in the air is short, the analysis efficiency is high, and the result is accurate.

The invention belongs to the technical field of oil-gas exploration and development, and provides a deep learning quantitative characterization method and system for the oiliness of a CT scanning oil layer. The method comprises the following steps: determining CT scanning parameters through an oil layer digital intelligent model to obtain an oil layer three-dimensional grayscale image, and comparing the oil layer three-dimensional grayscale image with an electron microscope image to establish a standardized three-dimensional digital model; establishing a deep learning standard model by using a convolutional neural network on the basis, and extracting parameters such as oil content and oil saturation; a judgment standard is determined according to sample experiments and analysis, evaluation standards and digital three-dimensional models of different types of oil layers are constructed, and then dominant target layer sections are screened out. The system comprises a data acquisition module, a model construction module, a parameter extraction module and an evaluation decision module and is used for realizing the method. According to the method, the problem of inaccurate existing measurement is solved, the authenticity and the accuracy of quantitative prediction of the oiliness of the oil layer are improved, the petroleum exploration and development efficiency is improved, and the cost is reduced.

The invention relates to the technical field of oil exploration and development, in particular to a method for quantitatively determining the completion probability of water-drive oilfield development and production allocation. The method comprises the steps of selecting a target water-drive oil field and determining a target research area, analyzing uncertainty factors influencing the yield scale of the target water-drive oil field and extracting key indexes, and counting historical development data of batch wells in the current year in the target research area, quantitative characterization is carried out on the key indexes, expected yield values of the target water-driven oil field under different probability conditions are calculated, the risk degree range of the production allocation yield of the target water-driven oil field is obtained, and a risk assessment model of the production allocation yield of the target water-driven oil field is established according to the range; and reasonably predicting the yield of the next target water-driven oil field to complete the task according to risk analysis and evaluation of the model on the production allocation yield of the target water-driven oil field. According to the method, the feasibility target of the target water drive oil field is formulated through scientific guidance, the yield risk is avoided in time, and planning deployment is adjusted in time.

The invention relates to the field of petroleum geology in the petroleum exploration industry, in particular to a foreland thrust zone development and evolution method and device, computer equipment and a storage medium, and the method comprises the steps: obtaining rock physical parameters of a to-be-determined region; performing biaxial experimental numerical simulation on the rock physical parameters to obtain microscopic parameters of different lithology or different stratums of the to-be-determined area; setting boundary conditions for the established geologic model, and carrying out a numerical simulation experiment according to regular changes of control variables of the geologic model to obtain a numerical simulation experiment result; and constructing extrusion according to a numerical simulation experiment result to obtain development and evolution of the foreland thrust zone of the to-be-determined area. By integrating limited geological and geophysical data, a geometric model and a geologic model can be established for a research area, and the forward modeling of the development and evolution process of the foreland thrust zone can be carried out by regularly adjusting partial parameters or anomalous bodies with relatively low cognition degrees.

A method for evaluating contribution of each component to shale oil reservoir resistivity at high temperature and high pressure is applied to the field of oil exploration and development. The method comprises the following steps: (1) analyzing the volume percentage of each clay mineral, the pore water content and the mineralization degree of the shale oil reservoir pressure-maintaining closed core; (2) when the fluid pressure is greater than 23MPa, measuring the resistivity of the pressure-maintaining closed rock core at each temperature point; (3) carrying out water balance treatment on pure clay minerals, namely kaolinite, montmorillonite, illite and chlorite, and measuring the resistivity at each temperature point when the fluid pressure is greater than 23MPa; (4) when the fluid pressure is greater than 23MPa, measuring the resistivity of each temperature point of the solution consistent with the mineralization degree of the pore water; and (5) constructing a resistivity evaluation model, and evaluating the contribution of each component to the resistivity of the shale oil reservoir under the condition of high temperature pressure.

The embodiment of the invention relates to the technical field of oil exploration and development, in particular to a shale reservoir compressibility calculation method, device and equipment, and the method comprises the steps: obtaining a rock sample of a shale reservoir on a construction site; calculating the bedding development index of the rock sample; the bedding development index represents the bedding structure development degree of the rock sample; performing a triaxial compression experiment on the rock sample under the simulated shale reservoir environment to obtain a brittleness index of the rock sample; the brittleness index represents the strain degree of brittle fracture of the rock sample; scanning the rock sample after the triaxial compression experiment to obtain a fractal dimension index of the rock sample; the fractal dimension index represents the space structure complexity of the three-dimensional crack in the rock sample; and calculating the compressibility of the shale reservoir according to the bedding development index, the brittleness index and the fractal dimension index. According to the embodiment of the invention, the compressibility of the shale reservoir can be accurately and quickly evaluated on the construction site by integrating the bedding structure development degree, the fracture strain degree and the space structure complexity of the rock sample.

The invention relates to the technical field of oil exploration, in particular to a shale oil dessert evaluation system construction method and a shale oil dessert evaluation method.The shale oil dessert evaluation system construction method comprises the steps that geological characteristic parameters of a plurality of rock core samples are obtained; based on the geological characteristic parameters, determining main control influence factors of shale oil enrichment through a control variable method and correlation analysis; and establishing a dessert section quantitative evaluation system according to the master control influence factors. According to the method, on the basis of the geological parameter data of the sampled rock core, through the control variable method and the correlation analysis method, the sweet spot evaluation parameter system is established, the sweet spot section of the pure shale layer section is longitudinally divided, the favorable area can be further predicted, and the technical problem of the method faced by shale oil sweet spot selection is solved. The shale oil enrichment mechanism, dessert control factors and favorable zone evaluation in the research section are deeply understood; meanwhile, reference is provided for area selection, zone selection and exploration deployment of the pure shale type shale oil, and the field of exploration of the pure shale type shale oil is effectively expanded.

The invention relates to the technical field of continuous light dydrocarbon, in particular to a dynamic configuration device and method for a continuous light dydrocarbon standard sample. Comprising a device main body, a driving unit, a sample feeding assembly and a sample discharging assembly, the device main body comprises a constant temperature layer and a sample preparation bin which are arranged from outside to inside, the sample preparation bin comprises a first bin body and a second bin body, and the opposite ends of the first bin body and the second bin body are respectively connected with a driving unit; according to the device, automatic operation of the whole process can be achieved, and manual intervention intensity and operation errors are greatly reduced; the standard sample concentration output by the device is accurate, stable and good in repeatability, system errors caused by standard sample concentration deviation of the light hydrocarbon instrument can be effectively inhibited, errors of hydrocarbon component content detection are controlled within a low range, the reliability of oil-gas-water layer recognition and evaluation results is remarkably improved, solid data support is provided for oil exploration and development, and the method is suitable for popularization and application. And the exploration decision risk is reduced.

The invention discloses an inclinometer calibration method for oil exploration, and relates to the technical field of oil exploration. Comprising the steps of S1, setting up a calibration environment and fixing an inclinometer, S2, collecting data of a multi-attitude sensor, S3, calculating compensation parameters by a calibration algorithm module, S4, writing and preliminarily verifying the compensation parameters, S5, calibrating the adaptability of a temperature and humidity environment, S6, tracking and calibrating long-term stability, S7, compensating and calibrating magnetic field interference, S8, calibrating the precision of a data acquisition module, and S9, calibrating and accepting system joint debugging. Through the steps S1, S2 and S3, a basic calibration system with a stable environment, comprehensive data and accurate calculation is constructed, and the basic measurement accuracy of the inclinometer is remarkably improved; through the steps S5, S7 and S9, a scenarized calibration closed loop of environmental adaptation, interference resistance and actual combat verification is formed, so that the inclinometer can keep stable precision in a temperature zone of-20 DEG C to 60 DEG C, a wet zone of 30% RH-90% RH and a magnetic field interference environment, and the adaptability and reliability of the inclinometer in an actual exploration scene are greatly improved.

The invention relates to the technical field of oil exploration logging data processing, and discloses a far exploration sound wave migration imaging data three-dimensional well trajectory correction method and related device.The method comprises the steps that horizontal well logging data are collected, coordinates of a well trajectory in space are obtained through calculation according to the horizontal well logging data, and the coordinates of the well trajectory are calculated according to the coordinates; the well track is drawn according to the coordinates of the well track in the space; generating migration imaging data in different directions according to the remote exploration acoustic logging data, and generating a migration imaging picture by using a color code according to the migration imaging data; the migration imaging picture is cut into a plurality of narrow strip pictures in the direction perpendicular to the well axis, all the narrow strip pictures are sequentially drawn into designed grids, migration imaging pictures generated by migration imaging data in different directions are sequentially drawn into a three-dimensional space, and horizontal well three-dimensional well trajectory correction of the migration imaging data is completed. According to the method, the accuracy of depicting the spatial relationship of geological reflectors such as stratum interfaces, faults and cracks near a horizontal well shaft by far-detection sound waves is improved.

The utility model relates to the technical field of oil exploration drilling equipment, in particular to oil exploration drilling equipment with a drill bit convenient to replace, which comprises a base, a fixing nail, a hydraulic rod, a connecting cylinder, a driving motor, a connecting rod, a fixing cylinder, a fixing seat and an excavating drill bit. Multiple sets of fixing nails are arranged at the bottom of the outer side of the base, a hydraulic rod is arranged on the inner side of the upper portion of the base, a connecting cylinder is arranged at the bottom of the hydraulic rod, a driving motor is arranged in the connecting cylinder, a connecting rod is arranged at the bottom of the connecting cylinder, a fixing cylinder is arranged at the bottom of the connecting rod, and a fixing base is arranged at the bottom of the fixing cylinder. Excavating drill bits are arranged at the bottom of the fixed seat; by adding the structure convenient to disassemble and assemble, the drill bit can be quickly disassembled for replacement when drill bits with different diameters need to be replaced or the drill bit is damaged, meanwhile, the drill bit with the replaceable excavating part is used, only parts at the excavating part are replaced when the drill bit is abraded, equipment needing to be carried is reduced, and the cost is reduced. And the practical value of the device is increased.

This disclosure relates to the field of petroleum exploration and development technology, and in particular to a method and system for determining bottom water intrusion characteristics. The method includes: determining the water permeability and the correlation coefficients between the matrix and fractures in a target block of a fractured sandstone gas reservoir; establishing and solving a mathematical model for cylindrical bottom water intrusion in a single well of the fractured sandstone gas reservoir based on the determined water permeability and the correlation coefficients between the matrix and fractures, obtaining a pressure function representing the difference between the original water pressure and the pressure at any point within the gas reservoir; using the obtained pressure function, determining the dimensionless bottom water intrusion volume; and determining the cylindrical bottom water intrusion characteristics of the dimensionless bottom water intrusion volume with respect to dimensionless time based on the determined dimensionless bottom water intrusion volume. By establishing a mathematical model of bottom water intrusion and calculating the cumulative water intrusion volume, the bottom water intrusion characteristics are determined, enabling an understanding of the entire dynamic process of bottom water intrusion in the reservoir.

This invention belongs to the field of petroleum exploration technology, specifically disclosing a formation pressure prediction method and system based on PSO-CNN-RF-ABKDE. The method includes: collecting logging data of deep abnormal pressure zones in the target well and adjacent wells, regional geological data, and measured pore pressure data from adjacent wells; preprocessing the acquired data; constructing a PSO-CNN-RF model; quantifying the uncertainty of the n-value prediction using the adaptive bandwidth kernel function density estimation ABKDE algorithm; outputting the n-value confidence interval by fitting the residual probability distribution; classifying the formation pressure risk level by combining the general pressure coefficient threshold for deep abnormal pressure; and substituting the n-value confidence interval into the PSO-CNN-RF model to obtain the predicted formation pressure result and mapping it to the specific formation pressure risk level. Compared with existing technologies, this invention achieves a direct mapping between prediction results and risk levels, quantifies uncertainty while clarifying control requirements, and provides a full-chain technical support of "prediction-quantification-control" for drilling safety in deep abnormal pressure zones.

The present invention provides a method for evaluating the dynamic shear capacity of a ram blowout preventer, which relates to the technical field of petroleum exploration and development. The dynamic shear stress calculation step adopts a three-parameter generalized strength criterion under the coupling of tension, compression, and shear according to the stress state of the ram blowout preventer during the shearing process, and analyzes and derives the stress distribution of the drill pipe under the dynamic working condition to obtain a theoretical formula for stress calculation of the drill pipe; the shear force estimation step uses the equivalent relationship between the ram shear and compressive stresses and the material yield criterion theory to obtain the shear resultant force F; the external force on the shear ram in its movement direction is comprehensively considered to calculate the ram comprehensive shear force F. max The evaluation method of the present invention introduces a three-parameter generalized strength criterion under the coupled effects of tension, compression, and shear, and proposes a method for constructing a theoretical model for calculating dynamic drill pipe shear stress, which has high applicability. The present invention also relates to a dynamic shear capacity evaluation device for a gate blowout preventer, which can be tested and inspected.

1. Name of the product in this design: Demonstration Device (Petroleum Exploration Equipment "Xuanji" System). 2. Purpose of this design: This design is a device for demonstrating digital twin models. 3. The key design feature of this product is its shape. 4. The image or photograph that best illustrates the key design points: Design 1 3D view. 5. The bottom surface of this product is a part that is not easily seen or cannot be seen during use, so the bottom views of Design 1 and Design 2 are omitted. 6. Design 1 is designated as the basic design.

The application discloses a petroleum drilling fluid aftereffect homing method, device, equipment and medium, and relates to the technical field of petroleum exploration. The method comprises the following steps: obtaining a target drilling fluid sample with bubble oil flower characteristics during drilling; analyzing and testing the target drilling fluid sample by means of logging technology to obtain n-alkane and isomeric alkane data corresponding to the target drilling fluid sample; determining chromatographic total hydrocarbon parameters and chromatographic component parameters according to the n-alkane and isomeric alkane data corresponding to the target drilling fluid sample; comparing and analyzing the chromatographic total hydrocarbon parameters and the chromatographic component parameters with total hydrocarbon parameters and component parameters of cuttings at different depths in a layer with oil and gas shows during drilling operation to determine the depth corresponding to the target drilling fluid sample and to homing the drilling fluid aftereffect with the bubble oil flower characteristics. In conclusion, the application can reduce the affected factors and make the homing error of the petroleum drilling fluid smaller.

This invention belongs to the field of petroleum exploration and discloses a quantitative characterization method for structural fracture parameters based on the coupling of the minimum energy consumption and minimum action principle. To overcome the shortcomings of existing technologies in achieving quantitative prediction of structural fractures from qualitative description, this invention first calculates the energy consumption of fracture rupture through rock mechanics experiments; then, it couples the minimum energy consumption principle and the minimum action principle to establish a rock fracture criterion; based on this, it derives and establishes quantitative characterization models for fracture aperture, volumetric density, and linear density; subsequently, it constructs a heterogeneous mechanical parameter volumetric model and performs elastoplastic geostress field simulation; finally, it achieves batch prediction of structural fracture parameters through programming, and verifies the reliability of the prediction results using core, imaging logging, and production dynamic data. This invention, starting from the physical essence of energy distribution and path selection, provides a unified theoretical framework for rock fracture and significantly improves the prediction accuracy of fracture "sweet spots."

The invention provides a fluid identification method and device, terminal equipment and a machine readable storage medium, and belongs to the field of oil exploration, and the identification method comprises the steps: determining a research sample well logging curve, a research sample gas logging curve and well drilling detection parameters; establishing a shallow resistivity and deep resistivity cross plot based on a research sample logging curve, and identifying water from unknown fluid; establishing a derivative parameter cross plot by using the research sample gas logging curve; establishing a density porosity and neutron porosity semi-quantitative evaluation CO2 content chart and a density porosity and porosity difference semi-quantitative evaluation CO2 content chart by utilizing a research sample well logging curve and well drilling detection parameters; and identifying CO2, condensate gas and oil in the unknown fluid based on the derived parameter cross plot, the CO2 content chart of the density porosity and neutron porosity semi-quantitative evaluation and the CO2 content chart of the density porosity and porosity difference semi-quantitative evaluation. Through the method provided by the invention, the unknown fluid can be accurately identified, and the well logging interpretation evaluation precision is improved.

The invention discloses a complex structure stratum while-drilling azimuth electromagnetic wave logging parameterization inversion method, and belongs to the field of oil exploration and development. The method comprises the following steps: s1, modeling a complex geologic structure, constructing a 2D complex geologic model, and parameterizing the 2D complex geologic model; s2, analyzing response characteristics of the 2D complex geological model according to the 2D complex geological model established in the s1, and carrying out influence factor and sensitivity analysis; s3, obtaining observation data according to response characteristics of s2, and constructing an objective function; and s4, in combination with s2 and s3, performing inversion on the parameterized 2D complex geological model by using a PT-MCMC inversion method to realize fine reconstruction of the complex stratum. According to the method, fine reconstruction of the complex stratum is achieved, good inversion precision is achieved, and the characterization capacity and the calculation efficiency are both considered. The method provides support for real-time geosteering, reservoir evaluation, layer interface prediction and the like of oil and gas fields.

This invention provides a method and system for identifying pores in core images, belonging to the field of petroleum exploration and development. The method involves adding DropBlock and BN layers to the convolutional blocks of the original U-Net network to obtain a reconstructed convolutional block. Furthermore, the feature pyramid module (FPN) replaces the jumps between upsampling and downsampling in the original U-Net model to obtain an improved U-Net architecture. The improved U-Net architecture is trained to obtain a pore identification model for identifying core images. The image to be tested is input into the pore identification model to obtain pore identification results for the core image. This method enhances the stability and reliability of prediction results, helping operators make faster decisions and optimize petroleum exploration and development plans.

The present invention discloses a method for suppressing interlayer multiple waves based on the scattered wave field series method, comprising the following steps performed in sequence: S1, analysis of the source of interlayer multiple waves; S2, data preparation; S3, prediction of the multiple wave model; S4, adaptive subtraction; S5, recovery of pre-stack gathers, and then superposition. The method provided by the present invention is completely data-driven for suppressing interlayer multiple waves, does not require manual intervention, does not require much prior information, and can better meet the requirements of suppressing interlayer multiple waves in complex structural areas, and can predict all interlayer multiple waves at once. By using this method, suppressing interlayer multiple waves can improve the imaging of large-set stratum interfaces of data, enhance lateral traceability, improve the imaging quality of data, and be more conducive to subsequent data interpretation. The present invention belongs to the field of petroleum exploration technology and can better meet the requirements of suppressing interlayer multiple waves.

The invention discloses an oil gas hydrocarbon generation pressurization charging wave and range characterization method based on energy conservation, and relates to the technical field of oil exploration and development. In order to solve the problem that a traditional method focuses on macroscopic reservoir formation qualitative description and lacks a filling degree accurate quantification method, energy of different sources is superposed to calculate total hydrocarbon expulsion kinetic energy of hydrocarbon expulsion of hydrocarbon source rocks; the energy from different sources comprises under-compaction kinetic energy, hydrocarbon generation volume expansion kinetic energy and fluid elasticity energy; quantizing the energy attenuation of the oil gas in the migration process from the hydrocarbon source rock to the reservoir; a charge distance limit is determined based on the total hydrocarbon expulsion kinetic energy and the energy attenuation of the migration process.

The invention relates to the technical field of oil exploration, in particular to a quantitative prediction method for dynamic permeability of fractures of fractured oil and gas reservoirs. According to the method, an underground crack-free rock core sample is adopted for artificial crack forming, and a relation chart of the confining pressure and the actually-measured crack permeability is obtained; the method comprises the following steps: predicting effective stress change in a development process by utilizing actual measurement formation pressure data of a single well, carrying out numerical simulation of effective stress in the development process on the basis of finite element modeling, and determining a relationship between effective stress of a target well and production time; and establishing a relationship between the effective stress of the target well and the fracture permeability in combination with a calculation result of the fracture permeability of the single well imaging logging, and further establishing a relationship between the production time and the fracture dynamic permeability, thereby realizing quantitative prediction of the change of the fracture dynamic permeability in the development process.

The invention belongs to the field of oil exploration, and discloses a quantitative characterization method for tectonic fracture parameters based on minimum energy consumption-minimum action principle coupling. In order to overcome the defect of difficulty in realizing qualitative description to quantitative prediction of a tectonic fracture in the prior art, the method comprises the following steps: firstly, calculating fracture energy consumption through a rock mechanics experiment; coupling a minimum energy consumption principle and a minimum action quantity principle, and establishing a rock fracture criterion; on the basis, a quantitative characterization model of the fracture opening, the volume density and the linear density is deduced and established; then constructing a heterogeneous mechanical parameter body model and carrying out elastic-plastic crustal stress field simulation; and finally, batch prediction of tectonic fracture parameters is realized through programming, and reliability verification is carried out on a prediction result by using rock core, imaging logging and production dynamic data. According to the method, a unified theoretical framework is provided for rock fracture from the physical essence of energy distribution and path selection, and the prediction precision of the crack sweet spot area is remarkably improved.

The invention discloses a quantitative evaluation method for resistivity heterogeneity of logging fusion formation water, and relates to the technical field of oil exploration and development. The method comprises the following steps of: obtaining formation signal data acquired by various logging and calculating reference formation water resistivity; a machine learning model is constructed based on feature data extracted from conventional logging, the formation water resistivity is a target variable of the machine learning model, and the machine learning model is trained to obtain a formation water resistivity prediction model; collecting conventional logging data, extracting feature data in the conventional logging data, inputting the feature data into the formation water resistivity prediction model, and outputting a formation resistivity prediction value; the formation resistivity prediction values of multiple depths form a continuous prediction curve to serve as a quantitative evaluation result of formation water resistivity heterogeneity, and the problem of accurate evaluation in the absence of nuclear magnetic resonance logging data is solved.

The embodiment of the invention provides a method for determining the oil extraction effect of a rock core, and belongs to the field of oil exploration. The method comprises the following steps: saturating a rock core by using saturated oil, analyzing the saturated rock core, and determining a first nuclear magnetic resonance spectrum curve corresponding to the saturated rock core; performing a huff-puff gas injection experiment on the saturated rock core, analyzing the rock core subjected to the huff-puff gas injection experiment, and determining a second nuclear magnetic resonance spectrum curve corresponding to the rock core subjected to the huff-puff gas injection experiment, wherein the first nuclear magnetic resonance spectrum curve and the second nuclear magnetic resonance spectrum curve represent the change of nuclear magnetic amplitude along with relaxation time; and determining the recovery efficiency of the rock core according to the first nuclear magnetic resonance spectrum curve and the second nuclear magnetic resonance spectrum curve. According to the method for determining the oil extraction effect of the core, the change condition of the oil content in the core can be observed in real time, and the calculation accuracy of the core recovery efficiency is improved.

The invention relates to the technical field of oil exploration geology research, in particular to a geological stratified data interpolation calculation method. The method comprises the steps that a target research area is determined, a plurality of reference layer position wells in the target research area are selected, the top depth and the bottom depth corresponding to each reference layer position well are obtained, and the top depths and the bottom depths of all the reference layer position wells are ranked from small to large; determining a plurality of target horizon wells in the target research area, and calculating the top depth and the bottom depth of each target horizon well according to the number of the reference horizon wells near each target horizon well in cooperation with the sequence of the top depths and the bottom depths of the reference horizon wells in combination with an equal proportion interpolation calculation method; and performing batch statistics on the top depth and the bottom depth of each target horizon well, and generating horizon data corresponding to each target horizon well in the target research area. According to the method provided by the invention, the problems that the existing interpolation calculation method must be based on the characteristic curve, and the calculation efficiency is low and the accuracy is poor when the deep layer data and the boundary well are supplemented and lost are effectively solved.