82 results about "Diagenesis" patented technology

The invention discloses a method for analyzing diagenesis of clay minerals by combining physical simulation and numerical simulation, which comprises the following steps: selecting clay single minerals, and preparing a formation water solution; respectively filling the clay single mineral and the stratum water solution into a plurality of reaction kettles, and carrying out diagenesis physical simulation; establishing a numerical simulation model with the same physical simulation experiment condition, and outputting mineral and ion data; according to mineral and ion data, fitting a physical simulation experiment result and a numerical simulation result, and determining a mineral corrosion rate; and establishing a geologic model by taking the mineral dissolution rate as a reference, and performing clay single mineral diagenesis simulation within a geological time scale. According to the method, numerical simulation parameters are constrained by physical simulation experiment results, and comparison and verification of numerical simulation and physical simulation results are realized by adjusting mineral corrosion kinetic parameters in real time, so that the numerical simulation experiment results are close to actual conditions.

The application discloses a kind of cross-tectonic period diagenesis simulation device and method.The device includes fluid driving system, reaction solution supply system and at least two groups of tectonic period reaction system connected in sequence, and different reaction systems are used to simulate the temperature and pressure conditions when geological fluid passes through each target layer during cross-tectonic period.The method first restores the geological conditions when geological fluid passes through each target layer during cross-tectonic period according to petrology and geochemistry analysis, combined with tectonic evolution history, burial history and fluid injection history, establishes cross-tectonic period diagenesis model, determines geological fluid type, and then determines the process of geological stress driving high-pressure layer fluid to migrate to low-pressure layer, restores the geological conditions when geological fluid passes through each target layer during cross-tectonic period;According to the restored geological process and geological conditions, the forward simulation of fluid dissolution, cementation, metasomatism and other diagenesis during cross-tectonic period is carried out by using cross-tectonic period diagenesis simulation device.Provide basis for judging the diagenetic mechanism of reservoir rock after high temperature and high pressure and multi-stage tectonic evolution.

The invention provides an earthquake quantitative prediction method for the compaction effect intensity of carbonate rocks, and the method comprises the following steps: (1) carrying out the statistics and analysis of logging data and core analysis data of a compacted stratum in a to-be-analyzed region, and building a fitting relation between the apparent compaction rate and the longitudinal wave speed; (2) performing phase-control frequency-division inversion in combination with the seismic response characteristics, and then calculating and analyzing the actual longitudinal wave speed of the to-be-analyzed region; and (3) determining the distribution of the apparent compaction rate according to the fitting relation between the apparent compaction rate and the longitudinal wave speed obtained in the step (1) and the actual longitudinal wave speed obtained in the step (2). According to the carbonate rock diagenesis strength earthquake prediction method based on the apparent compaction rate, the problem that quantitative prediction of the carbonate rock compaction strength is difficult is solved, the distribution characteristics of different compaction strength in space are defined, and the exploration and development success rate can be improved.

Systems and methods for determining a diagenesis level in a reservoir for performing hydrocarbon extraction include receiving a set of open hole (OH) log data from one or more wells in the reservoir, the OH log data representing a subsurface of the reservoir; executing a diagenesis model to process the set of OH log data, the diagenesis model trained by thin-section image data correlated to labeled OH log data, the labeling identifying values for a quartz overgrowth rate (QOR), a clay coating rate (CCR), or a thin-section porosity in the subsurface based on a value in the OH log data; determining a prediction of a porosity of the reservoir, a permeability of the reservoir, or both the porosity and the permeability; and generating a control signal representing a recommendation to drill a well at a location in the reservoir.

The invention belongs to the technical field of oil and gas reservoir rock data identification, and particularly relates to a three-dimensional multi-mineral digital core modeling method. According to the method, a 2D-3DGAN algorithm is provided, a three-dimensional data volume can be generated only by using a single two-dimensional picture, the advantages of a 2D-3DGAN method and an AMICS method are combined, a modeling method of 'AMICS + 2D-3DGAN' is provided to establish a multi-mineral, high-precision and efficient three-dimensional multi-mineral digital core, the representative two-dimensional ore scanning image is obtained by using the 2D-3DGAN method, and the three-dimensional data volume can be generated only by using a single two-dimensional picture. And generating a three-dimensional multi-mineral digital image by using the obtained two-dimensional mine scanning image as a training image. The built model not only contains multiple minerals, but also gives consideration to accuracy and economical efficiency, can represent reservoir rocks, and provides a firm basis for subsequent diagenesis simulation based on multi-mineral digital cores and research on electrical, acoustic and mechanical properties of reservoirs.

Methods for seismic diagenetic modeling are disclosed. The methods include obtaining a seismic facies map, well data from one or more wells, and a burial map, and determining input parameters, a burial-history curve, and a thermal-history curve based on the well data. The methods may further include determining a sedimentary facies map based on the seismic facies map and the well data, for each of the sedimentary facies, determining a facies-dependent seismic diagenesis model based on the input parameters, the burial-history curve, the thermal-history curve, the sedimentary facies map, and models, determining a seismic diagenetic model based on the facies-dependent seismic diagenesis model for each of the sedimentary facies and the burial map, and determining an output map based on the seismic diagenetic model. The methods may further include identifying a drilling target based on the output map and designing a wellbore drilling plan based on the drilling target. Systems for seismic diagenetic modeling are also disclosed.

The invention relates to a method for identifying hydrothermal calcite in shale. The method comprises the following steps: preparing sample slices from calcite samples at the same layer and in different occurrence states; carrying out cathodoluminescence observation on the sample slice to obtain a cathodoluminescence picture; determining rare earth element data of each sample slice by utilizing an element geochemical analysis method; determining a forming mode of a sample slice according to the cathode luminescence photograph and the rare earth element data; wherein the formation mode comprises a later diagenesis mode and a hydrothermal deposition calcite mode.

The invention provides an improved authigenic mineral U-Pb dating method, and relates to the technical field of oil-gas exploration, and the method comprises the following steps: carrying out diagenetic age petrology analysis on a carbonate reservoir in a research area to prepare a plurality of parallel rock samples; carrying out diagenetic age microscopic mineralogical analysis on the parallel rock samples, and determining the diagenetic period of the carbonate reservoir in the research area; analyzing major elements, trace elements and rare earth elements of the parallel rock samples, determining a high U content area, and determining a diagenesis fluid source of the carbonate reservoir in the research area; and carrying out U-Pb isotope test analysis on the high U content region to obtain the diagenesis absolute age of different minerals or the same mineral of the carbonate reservoir in the research region. According to the method, dynamic quantitative recovery of the carbonate rock reservoir forming-reservoir forming dynamic process is achieved, and the defects that an existing method is low in dating success rate and high in test result multiplicity of solutions are overcome.

The invention relates to the technical field of lithofacies paleogeography and reservoir geology, in particular to a carbonate rock large-scale high-quality reservoir quantitative geological evaluation method, which comprises the following steps of: 1, determining compilation of a carbonate rock lithofacies base map; 2, identifying a carbonate rock paleogeographic pattern and a high-quality reservoir facies belt; 3, quantitatively depicting a high-quality reservoir sedimentary body, and expressing a geologic body structure; 4, judging the type of the storage space; and 5, analyzing the diagenesis and diagenesis sequence of the large-scale reservoir. According to the method, quantitative geological evaluation of the large-scale high-quality reservoir of the carbonate rock can be well carried out.

The invention relates to the technical field of shale oil exploration and development, in particular to a lamellar fracture secondary classification shale reservoir evaluation method. The method comprises the following steps: determining a target research area, respectively identifying brittle minerals and clay minerals of a shale sample in the research area, calibrating a shale deposition scale and a shale diagenesis scale, dividing lamellar fractures in the research area into deposition lamellar fractures and diagenesis lamellar fractures according to the shale deposition scale and the shale diagenesis scale, the method comprises the following steps: combining a sedimentary lamella fracture with a plurality of diagenetic lamella fractures to construct a lamella body, firstly calculating the lamella body thickness, the lamella body spacing, the lamella body penetration ratio and the lamella body curvature, then calculating an imbibition capability index, a seepage capability index and a development capability index, and finally evaluating the lamella development degree of the shale reservoir according to three obtained evaluation indexes. According to the method provided by the invention, the two-level division of the lamellitic seam level is realized, the lamellitic body is also constructed, and clear guidance can be provided for shale oil exploration and development.

The invention provides a sedimentary diagenesis facies seismic geology combined prediction method. The prediction method comprises the steps that S1, reservoir parameters and reservoir diagenesis facies types corresponding to reservoir core slices are determined; s2, determining pore structure types of multiple types of lithogenous phases; s3, classifying the sedimentary diagenetic facies, and dividing the sedimentary diagenetic facies into favorable sedimentary diagenetic facies and secondary favorable sedimentary diagenetic facies; s4, establishing a linear multivariate discriminant function of the sedimentary lithogenous phase; s5, determining the distribution characteristics of the sedimentary diagenesis facies on the single well; s6, rock physical elastic parameters of various wells are calculated; step S7, screening sensitive elastic parameters capable of distinguishing favorable sedimentary diagenesis phases and secondary favorable sedimentary diagenesis phases; and S8, determining the spatial distribution range of the favorable sedimentary lithogenous phase and the secondary favorable sedimentary lithogenous phase. And a foundation is laid for application of sedimentary diagenesis phase distribution characteristics in oil-gas exploration.

The invention discloses an anisotropic large-size artificial rock core preparation device and method. The device comprises a forming system used for providing a rock core forming environment, an axial pressure loading system used for simulating rock core stratum axial pressure, a confining pressure loading system used for simulating rock core stratum confining pressure, a pore pressure loading system used for simulating rock core stratum pore pressure and a heating system used for simulating rock core stratum temperature. The collecting and metering system is used for collecting discharged pore pressure fluid and respectively metering a gas phase and a liquid phase, the data acquisition system can acquire various information during preparation, and the control system is used for controlling the systems to work according to data fed back by the data acquisition system so as to simulate the diagenesis process of natural rock and recording and analyzing the data. According to the invention, a coupling environment of a real rock diagenesis process can be simulated, and anisotropy and reservoir heterogeneity can be simulated.

A chlorite growth process reconstruction method relates to the technical field of geological exploration, and mainly comprises the following steps: collecting well drilling core sample analysis related data, and preparing rock slices; analyzing the relationship between different deposition periods and environmental conditions and chlorite generation and growth; representing the composition and content of chlorite and other minerals in the rock slice; establishing the relationship between chlorite components and diagenesis evolution stages; collecting rock core sample diagenesis environment sediment samples; the method comprises the following steps: evaluating the influence of organic matters in sediments on chlorite formation, performing multi-scale coupling numerical simulation modeling, establishing a chlorite growth model, and reconstructing a chlorite growth process by using the chlorite growth model; according to the method, core sample analysis, sedimentary environment parameters and multi-scale coupling numerical simulation are comprehensively combined, so that growth evolution of chlorite in each diagenesis stage is clearly reconstructed, and a more accurate and reliable chlorite growth process is obtained.

The utility model discloses a diagenetic and metallogenic simulation test device which comprises a mantle simulation temperature zone, an earth crust simulation temperature zone and a pressurization system, the mantle simulation temperature area comprises a mantle temperature simulation area; the earth crust simulation temperature zone comprises an earth crust zone and an earth crust temperature control zone; the pressurization system comprises a sample pool and a high-pressure interface, the sample pool is connected to the earth crust area through the high-pressure interface, and the earth crust temperature control area and the mantle temperature simulation area are combined to form a closed-loop structure of the earth; a deep geological process and mineral phase change are researched by simulating high-temperature and high-pressure conditions in a geological environment, a sample is placed in high-temperature and high-pressure equipment, and a high-temperature and non-pressure-loss environment, similar to volcanic eruption but not to the surface of the earth, of deep molten slurry of the earth crust from a mantle to the earth crust is simulated by controlling temperature and pressure and adopting a rapid quenching mode; various diagenetic and metallogenic conditions within 10000 meters under the ground are adopted; and multi-temperature-zone control can be carried out, and the travel process and physical conditions of various minerals with the depth of 0-10000 meters on the earth surface can be met.

Systems and methods for determining a diagenesis level in a reservoir for performing hydrocarbon extraction include receiving a set of open hole (OH) log data from one or more wells in the reservoir, the OH log data representing a subsurface of the reservoir; executing a diagenesis model to process the set of OH log data, the diagenesis model trained by thin-section image data correlated to labeled OH log data, the labeling identifying values for a quartz overgrowth rate (QOR), a clay coating rate (CCR), or a thin-section porosity in the subsurface based on a value in the OH log data; determining a prediction of a porosity of the reservoir, a permeability of the reservoir, or both the porosity and the permeability; and generating a control signal representing a recommendation to drill a well at a location in the reservoir.

The invention provides a method for determining an oil and gas reservoir forming period based on xenotime in-situ U-Pb dating, which comprises the following steps: collecting a sedimentary rock sample of a petroliferous basin, selecting xenotime particles from the sedimentary rock sample, and carrying out in-situ U-Pb dating to obtain U-Pb age data of the sample; determining the rock thermal evolution history according to the U-Pb age; the method comprises the following steps: establishing a mapping model of a basin thermal evolution history and an oil and gas accumulation and accumulation period, matching a thermal evolution history after rock autodeposition and diagenesis with the mapping model of the basin thermal evolution history and the oil and gas accumulation and accumulation period, obtaining a period of an oil and gas accumulation event of a basin oil and gas reservoir, and determining the basin oil and gas accumulation period according to the period of the oil and gas accumulation event. According to the method, the early diagenesis is determined by using the xenotime, and the period of each main fluid and thermal event influencing the sedimentary basin can be determined, so that a breakthrough from'indirect inference 'to'direct dating' is realized, the dating precision of oil and gas reservoirs is improved, and the quantitative development of fluid activity research of the sedimentary basin is promoted.

The invention provides an intelligent sandstone slice identification system and an intelligent sandstone slice identification method, and belongs to the technical field of geological exploration. In the system, a data analysis module integrates three core algorithms: a data enhancement module adopts an improved conditional cycle consistency generative adversarial network to solve the problem of scarcity of rock samples; the multi-modal feature understanding module fuses image visual features and petrology text features by using a cross-modal attention mechanism; and the intelligent identification module completes recognition and classification of mineral composition, structure construction and diagenesis in parallel based on a multi-task learning architecture. The method comprises a system training stage and a sample identification stage. According to the method, the model generalization ability is improved by generating a large number of synthetic samples, the geological rationality of the identification result is enhanced through multi-modal semantic fusion, efficient, accurate and objective automatic intelligent identification of the sandstone slice is realized, and a key technical support is provided for reservoir evaluation in the field of petroleum geology.

The invention provides an iron-sulfur isotope equilibrium fractionation factor calculation method based on a density functional theory. The iron-sulfur isotope equilibrium fractionation factor calculation method comprises the following steps: firstly, constructing initial mineral models of amorphous FeS, cubic FeS, maquinol ore, hematite, hematite and pyrite; the model is optimized through a spin polarization DFT + U method, GGA-PBE functional, OTFG ultra-soft pseudo potential, 400 eV plane wave cutoff energy and 5.0 * 10 <-7 > Hartree self-consistent field convergence standards are selected as calculation parameters, and the optimal Hubbar Ueff value and magnetic sequence arrangement of each mineral are determined; and finally, calculating the simple harmonic vibration frequency of the mineral, and deducing equilibrium fractionation factors (1000ln beta value) of Fe and S isotopes at a specific temperature. According to the method, the theoretical blank of isotope fractionation of the conversion path from amorphous FeS to pyrite is filled up, the data can be used for judging the isotope balance of minerals and tracing the mineralization process, and an important theoretical basis is provided for research on sedimentary diagenesis and ancient ocean redox.

The application discloses a geothermal caprock multi-factor coupling evaluation system, which aims to solve the problems of low standardization degree of existing evaluation manual operation process, lack of unified engineering architecture of multi-factor coupling and insufficient result visualization. The application automatically executes caprock comprehensive evaluation on a unified platform through a data acquisition module, a single-factor evaluation module, a coupling model construction module, a coupling score calculation module, a comprehensive evaluation module and a result output module. The system completes single-factor scoring based on basic data, constructs and calculates the scores of four coupling subsystems of lithology-diagenesis-physical property, structure-mechanics-integrity, thickness-continuity and fluid-pressure-temperature, quantifies the coupling relationship between the subsystems by using a cross influence matrix to obtain the final score, and outputs the comprehensive score and the visualized result after weighting. The application realizes the integration and automation of the evaluation process, supports the engineering landing of complex coupling models, and improves the result visualization and decision support capability.

The present invention belongs to the field of coal mine water conservation and disaster reduction control, specifically a method for water conservation and disaster reduction of calcified induced diagenesis in the Quaternary loose layer; according to the impact range of underground coal mining on the Quaternary loose layer, the calcified water solution recharge drilling holes and the effect observation drilling holes are reasonably arranged; according to the ion composition and content of the water body stored in the Quaternary loose layer, a reagent aqueous solution of appropriate concentration is prepared; the calcium carbonate precipitation generated by the chemical reaction of groundwater and the calcified water solution is used to reinforce the loose sand / soil particles, promote the diagenesis of the sand / soil body in the corresponding area, and finally form a whole with a certain bearing capacity, prevent the large-scale transmission of the loose layer load, and prevent the occurrence of composite fractures in the key layer, thereby achieving the purpose of groundwater protection and geological disaster prevention and control. The present invention can provide guarantees for water conservation mining and strong mine pressure control in mining areas with thick loose layers and thin bedrock. Its implementation method is simple, safe, environmentally friendly, and highly reliable.

According to the quantitative logging prediction method for the corrosion strength of the carbonate rock, the corrosion effect standard sample which is obviously influenced by the corrosion effect is selected as a basis for establishing quantitative evaluation of the corrosion strength, and the corrosion effect standard sample is further verified. And then obtaining a target corrosion strength development index parameter capable of reflecting the corrosion strength, and depicting the corrosion strength of the pore type bioclastic limestone reservoir. According to the evaluation method, basic geological data are fully combined, the quantitative evaluation index of the corrosion strength is constructed according to the target corrosion strength development index parameters, and evaluation on the development scale difference of the pore type bioclastic limestone reservoir of the target interval is more in line with the actual condition of an oil field. According to the method, a specific quantitative method can be provided for depicting the corrosion strength of the existing pore type bioclastic limestone reservoir, the deficiency of diagenesis transformation between the carbonate rock facies and the reservoir is made up, the corrosion strength of the carbonate rock can be accurately described, and a foundation is laid for deterministic depiction of a reservoir unit.

The invention provides a rock brittleness index determination method and related equipment. The method comprises the following steps: performing a triaxial compression test on a rock to obtain a stress-strain curve; and determining the rock brittleness index based on the stress-strain curve. According to the scheme, the stress-strain curve can be obtained based on the rock triaxial compression test, the curve can reflect the energy evolution characteristics of the whole process from deformation starting to damage of the rock under the action of external force, and then the brittleness evaluation index is established. The method can comprehensively consider the brittleness influence factors of lithology, diagenesis, confining pressure, pore pressure and the like of the rock, and can continuously measure the brittleness change trend of the rock in the whole range from ideal plasticity to ideal brittleness. And furthermore, the accuracy of the determination result of the rock brittleness index is effectively improved.

The invention provides a geologic body description method and device and electronic equipment, and the method comprises the steps: calculating and extracting a boundary, a minimum bounding rectangle, a central point and eight quadrant division of a geologic body element through employing a spatial analysis method and geometric operation; extracting a geologic body data set contained in the geologic body elements, and calculating and determining the extension trend and area of the geologic body elements in the geologic body data set; analyzing and judging the spatial relationship between the geologic body elements and the eight quadrants and the distance between the geologic body elements and the geometric center point of the geologic body elements; extracting the landform information of the area where the geologic body elements are located and the spatial relationship between the geologic body elements and water systems, traffic and administrative divisions; screening and calculating the contact relationship between the geologic body elements and other geologic bodies, and carrying out classified statistics on information such as lithologic combination and diagenesis times of the contacted geologic bodies; and compiling a geologic body comprehensive information description framework model, and automatically generating a comprehensive description text of geologic body elements and comprehensive information statistics of contact geologic body rock combinations in combination with analysis and calculation results.

The invention provides an identification method for late formed rock corrosion of carbonate rocks. The method comprises the following steps: collecting a sampling sample from an underground rock core and a field outcrop sample; performing first observation treatment on the sampled sample to establish a sedimentary-diagenesis sequence, and preliminarily determining the type of the late diagenesis corrosion hole; performing second observation treatment on the sampled sample to identify the hydrocarbon inclusion state of the sampled sample; performing third observation treatment on the sampled sample to identify the uniform temperature and freezing point temperature of the gas-liquid two-phase fluid inclusion in the sampled sample; determining the content of main trace elements in the sampled sample; measuring the carbon and oxygen isotope value of the sampled sample; according to the sedimentary-diagenesis sequence, the type of the corrosion hole, the state of the hydrocarbon inclusion, the uniform temperature and freezing point temperature of the gas-liquid two-phase fluid inclusion, the content of main trace elements and the carbon and oxygen isotope value, the identification basis of late diagenesis corrosion of the carbonate rock is determined; the method is used for achieving the effect of improving the carbonate rock late formation rock corrosion identification efficiency.

The invention discloses a method for quantitatively determining contribution proportions of crude oil from different sources and periods. The method comprises the following steps: collecting a crude oil sample, a potential hydrocarbon source rock sample and a reservoir sample of a target oil and gas reservoir; comparing hydrocarbon isotopes and biomarker compounds of the crude oil sample and the potential hydrocarbon source rock samples, and determining a main hydrocarbon source rock; manufacturing an inclusion sheet; establishing a diagenesis mineral sequence of the target oil and gas reservoir; determining the capture periods of various hydrocarbon inclusions in the inclusion sheet; measuring the U-Pb age of the diagenetic minerals in each stage; determining each main reservoir forming period and the source of oil and gas in each main reservoir forming period; respectively measuring the fluorescence spectrum of the hydrocarbon inclusion corresponding to each main reservoir forming period; determining the fluorescence spectrum of the crude oil sample; according to the fluorescence spectrum of the crude oil sample and the fluorescence spectrum of the hydrocarbon inclusion, the contribution ratios of crude oil of different sources and periods are determined, so that quantitative analysis of the contribution ratios of different hydrocarbon source rocks in different reservoir forming periods is realized, and effective exploration deployment guidance can be provided.

The invention relates to a sweet spot reservoir prediction method based on source-sink-rock system coupling, and the method comprises the steps: constructing a sequence framework which comprises the steps: recognizing a single well sequence interface, carrying out the seismic sequence division of the sequence interface, and verifying the sequence interface through ancient biology; in the sequence framework, material source supply capacity calculation is carried out, a material source judgment system, an ancient landform recovery result and seismic attribute analysis are synthesized, sedimentary system distribution characteristics are identified, sedimentary facies belt prediction is carried out, and a sedimentary facies control sand body model is established; establishing a three-dimensional sand body distribution model based on the sequence framework, the distribution characteristics of the sedimentary system and the sedimentary facies control sand body model; a favorable zone is obtained through prediction according to seismic attributes of all system domains in the multiple sets of sand-rich deposition system distribution feature superposition coupling sequence grillages; and based on the three-dimensional sand body distribution model, and in combination with a reservoir diagenesis-physical property corresponding relationship summarized by single well actual measurement data, preferably selecting a sweet spot target in the favorable zone. According to the invention, the reliability of sweet spot reservoir prediction can be improved.

The present invention belongs to the fields of petroleum geology and tectono-diagenesis, and specifically discloses a method for determining the direction of the ancient maximum compressive stress during the formation of orthogonal tensile fractures. By combining the petrographic characteristics of fluid inclusions trapped in different minerals within orthogonal tensile fractures and the analysis of the development types of fluid inclusions, conducting laser Raman spectroscopy tests on methane-rich inclusions and microthermometric analysis of coexisting brine inclusions, using the pressure-volume-temperature simulation method to obtain the fluid pressure and temperature during the mineral crystallization process, combining the trapped temperature data with the burial history curve of this area, identifying the opening process and state of two groups of orthogonal tensile fractures, obtaining the time coupling relationship when the orthogonal tensile fractures are in the open state, and finally obtaining the direction of the ancient maximum compressive stress during the simultaneous opening process of the orthogonal tensile fractures according to tectonic stress analysis. It provides a new idea and method for judging the direction of the ancient maximum compressive stress during the formation of orthogonal tensile fractures.

The invention belongs to the field of petroleum geology and tectonic-diagenesis, and particularly discloses a method for limiting the paleo-maximum compressive stress direction when an orthogonal tensional fracture is formed. Analyzing the lithofacies characteristics of fluid inclusions captured in different minerals in the orthogonal tensional fracture and the development types of the fluid inclusions, performing laser Raman spectrum testing on the methane-rich inclusions, and performing microscopic temperature measurement analysis on the symbiotic brine inclusions; the fluid pressure and temperature in the mineral crystallization process are obtained through a pressure-volume-temperature simulation method, captured temperature data are combined with a burial history curve of the region, the opening process and state of two groups of orthogonal tensional fractures are judged, the time coupling relation that the orthogonal tensional fractures are in the opening state is obtained, and according to tectonic stress analysis, the time coupling relation of the orthogonal tensional fractures in the opening state is calculated. And finally, obtaining the ancient maximum pressure stress direction in the simultaneous opening process of the orthogonal tensile crack. And a new thought and method are provided for judging the ancient maximum compressive stress direction when the orthogonal tensional crack is formed.

This invention belongs to the field of oil and gas reservoir rock data identification technology, and particularly relates to a three-dimensional multi-mineral digital core modeling method. This application proposes a 2D-3DGAN algorithm, which can generate a three-dimensional data volume using only a single two-dimensional image. By combining the advantages of the 2D-3DGAN and AMICS methods, a "AMICS+2D-3DGAN" modeling method is proposed to achieve the establishment of multi-mineral, high-precision, and efficient three-dimensional multi-mineral digital cores. The former is used to obtain representative two-dimensional mineral scanning images, while the latter uses these two-dimensional scanning images as training images to generate three-dimensional multi-mineral digital images. The established model not only includes multiple minerals but also considers accuracy and economy, and can represent reservoir rocks, providing a solid foundation for subsequent diagenetic simulation based on multi-mineral digital cores, as well as research on reservoir electrical, acoustic, and mechanical properties.

The invention provides a reservoir productivity assessment method and device and related equipment, and the method comprises the steps: obtaining the logging data of a to-be-assessed reservoir target region, and the logging data comprise density logging data and interval transit time logging data; determining a fracturing index according to the logging data; determining a productivity index according to the fracturing index; and evaluating the productivity of the target region of the reservoir to be evaluated according to the productivity index. According to the method and the device, on the basis of a composite index, namely a fracturing index, factors such as inherent attributes of rock mechanics, diagenesis and influence of a crustal stress field on the complexity degree and the transformation volume of a reservoir fracturing fracture network can be comprehensively considered, the reservoir fracturing performance is continuously evaluated, the matching rate of a reservoir fracturing performance evaluation result and an actual condition is increased, and the evaluation accuracy of the reservoir fracturing performance is improved. And the selection precision of the fracturable interval is improved, and the multi-stage fracturing design precision is improved, so that the reservoir productivity evaluation precision is improved.