26 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.

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.

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 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 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.

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.

According to the method for measuring the true density of the coal rock, provided by the invention, different evolution stages experienced by the coal rock in a complex geological history can be efficiently and accurately identified. The stages cover the initial diagenesis to the later metamorphism, and each stage is accompanied by significant changes of physical and chemical properties of the coal rock. Besides, the method also has excellent distinguishing capability, the carbonaceous mudstone can be clearly and effectively distinguished from other types of coal rocks, and the carbonaceous mudstone is used as a special sedimentary rock, has complex components, often contains relatively high organic matters, and has significant difference from conventional coal rocks in multiple aspects. Therefore, the method not only contributes to deepening the understanding of the formation cause and the evolution process of the coal rock, but also provides important technical support and scientific basis for the fields of exploration and development of coal resources, environmental protection and the like.

The invention provides a sedimentary-diagenesis coupling effect quantitative characterization and favorable zone evaluation method for dense sandstone reservoir dessert prediction, which comprises the following steps: modeling geological effects such as deposition, compaction, cementation, cracks and the like into a Markov decision process, and defining an instant reward function to quantify porosity and permeability evolution; the Wasserstein distance and the quantitative modal logic are adopted to measure the one-step evolution similarity and the multi-step evolution similarity; generating a specific evolution process by using the bound variable abstract syntax tree and single variable substitution; comparing with a historical dessert template to calculate a mixing metric, screening dessert candidate units, and clustering to form a favorable zone; and finally, combining budget and risk to construct a multi-selection knapsack model, and optimizing an optimal development scheme under constraints. According to the method, the comprehensive influence of the sedimentary-diagenesis coupling effect on the porosity and permeability can be accurately depicted, and quantitative prediction and guided development of a high porosity and permeability potential zone are achieved.

The invention discloses a bioclastic limestone sedimentary mode construction method and system, and belongs to the technical field of carbonate rock sedimentary, and the bioclastic limestone sedimentary mode construction method comprises the steps of reversely deducing biological types and rock structures, and carrying out primary correction and secondary correction on a theoretical sedimentary mode. By adopting multiple geological control factors, tectonic scene control, sedimentary environment control, sequence stratigraphic cycle control and Wafer facies law control, the accuracy of the model is improved under the control of the multiple geological factors, the model is matched with geological cognition of different subjects, original sedimentary biological debris is reversely deduced on the basis of a diagenetic mode, and the stratum sequence stratigraphic cycle control and the Wafer facies law control are combined. The interference of diagenesis is eliminated; according to the biological shell particle size and the structure maturity, the concept deposition mode is continuously corrected, and the defects that the bioclastic limestone is subjected to non-in-situ deposition, and the indication of organisms to the deposition environment is weak are overcome.

The invention discloses a method for evaluating the influence of a coated clay cladding on reservoir quality, and relates to the technical field of oil and gas reservoir evaluation and petroleum geological prospecting, and the method comprises the following steps: S1, obtaining basic parameters: obtaining petrology parameters, clay cladding parameters, geochemical parameters and geological environment parameters of a target reservoir; s2, constructing a reactive transport model; s3, multi-scenario simulation operation: operating the model, and respectively simulating mineral dissolution and precipitation processes and porosity evolution of the target reservoir under two scenarios of CO2 enriched fluid and organic acid enriched fluid; and S4, comprehensive evaluation and result output: comparing and analyzing simulation results under two situations of CO2 enrichment fluid and organic acid enrichment fluid, outputting a net porosity variation value and a dominant diagenesis mechanism, and finally evaluating the quality influence of the clay cladding reservoir according to the net porosity variation value and the dominant diagenesis mechanism, so as to realize dynamic, quantitative and accurate evaluation. The problem of reservoir quality prediction caused by clay cladding dual effects is solved.

This invention belongs to the field of hydrocarbon accumulation analysis and simulation technology in oil and gas exploration, specifically involving a method for analyzing the coupling relationship between formation water and reservoir based on salinity evolution. This invention employs seven steps: restoring the paleosalinity of original formation water during the sedimentary period, analyzing the ion exchange between water and rock during diagenesis, analyzing the salinity of inclusions during reservoir formation, analyzing the impact of later adjustments and alterations, analyzing the current formation water salinity, deriving the relationship between salinity and reservoir, and applying the results to the precise identification of complex oil-bearing layers through well logging. It analyzes the evolution of paleosalinity of formation water during sedimentation, diagenesis, and reservoir formation, clarifies the influence of later tectonic activity on formation water properties, and provides a case study of the evolution process of formation water salinity in different fluid systems of the Mesozoic Yanchang Formation in a basin. Through the analysis of the formation water salinity evolution process, it identifies the influence of sedimentation, diagenesis, reservoir formation, and later adjustments, and comprehensively utilizes the relationship between formation water properties and reservoir, providing a basis for the precise identification of complex oil-bearing layers through well logging.

This application relates to the field of oil and gas field exploration and development technology, and in particular to a method, apparatus, equipment, storage medium, and computer program product for determining the time required for closure after fracture activity in source rock formations. The method determines the diagenesis degree-time curve of the fracture zone based on the pressure of the overlying strata and the diagenesis time of the fracture zone; it determines the diagenesis degree-time curve of the surrounding rock based on the static rock pressure and the diagenesis time of the surrounding rock; based on the diagenesis degree-time curves of the fracture zone and the surrounding rock, it matches the diagenesis degree of the fracture zone and the surrounding rock to determine the rock valve pressure of the fracture zone corresponding to the time point when the diagenesis degree is equal; based on the rock valve pressure of the fracture zone, it determines the valve pressure diagenesis time curve of the fracture zone; and based on the preset maximum valve pressure of the source rock formation and the valve pressure diagenesis time curve, it determines the target closure time, thus improving the prediction accuracy of the time required to reach a closed state after the fracture stops.

Systems and methods for integrating depositional and diagenetic modeling. A model integration tool decodes a depositional parameter of a geological environment generated in response to depositional modeling by a depositional modeling engine. The model integration tool also discretizes the depositional parameter in a three dimensional (3D) volume. Further, the model integration tool extracts a targeted sub-volume of the 3D volume of the depositional parameter. Additionally, the model integration tool converts the depositional parameter into a diagenetic parameter to perform diagenetic modeling on the diagenetic parameter. Accordingly, the depositional modeling engine performs diagenetic modeling with the updated diagenetic parameter. Additionally, the model integration tool appends the updated depositional parameter and diagenetic modeling results to the data characterizing the geological environment.

The present application provides a kind of bioclastical limestone reservoir diagenesis semi-quantitative evaluation method, comprising: step 1: carbonate reservoir diagenesis is divided according to preset standard;Step 2: obtain the carbonate reservoir image of target research area;Step 3: the carbonate reservoir image is labeled according to the preset standard;Step 4: the labeling result is counted, and the diagenesis of the carbonate reservoir in the target research area is semi-quantitatively evaluated according to the statistical result.The method provided by the present application can semi-quantitatively evaluate the diagenesis of carbonate reservoir, semi-quantitatively characterize the development degree of secondary pores and the content of different period cement, so as to help to determine the diagenetic difference of different development layer series, and finally provide guidance for oil and gas field development deployment.

The application provides a method and device for diagenetic strength analysis of oil and gas reservoir rocks, which comprises the following steps: determining the common boundary of each adjacent mineral particle in a mineral binary image obtained based on a preset common boundary extraction algorithm, to obtain a particle boundary extraction result image; determining the maximum circumscribed rectangle of each mineral particle, and calculating the total equivalent particle diameter of all mineral particles; performing image processing based on a preset image processing algorithm, to obtain a mineral morphological gradient image and a mineral watershed line image; performing logical AND operation, to obtain a logical operation result image; performing color space transformation, to obtain a mineral particle contact image; calculating the total point contact length and the total line contact length according to the mineral particle contact image; and obtaining a diagenetic strength coefficient according to the total equivalent particle diameter of all mineral particles, the total point contact length and the total line contact length. The result is accurate because the mineral automatic analysis image is used for automatic quantitative calculation.

The application discloses a kind of heterogeneous compact reservoir difference evolution model construction methods, belong to oil and gas geological exploration technical field, this method includes five core steps: first, core, experiment, well logging and seismic multi-source data are standardized and preprocessed;Then quantitative analysis reservoir porosity, permeability temporal and spatial variation and pore throat characteristics;Then dynamic source rock diagenesis process and quantize its intensity;Further, key factors such as sedimentary microfacies, diagenetic transformation intensity, tectonic activity frequency and burial depth are coupled, and the correlation function between them and reservoir densification degree is established;Finally, a visual model is constructed and optimized by validation data and regional geological background factors.The application solves the problems of multi-source data integration, evolution law quantization and poor model applicability, realizes the integrated dynamic characterization from micro-pore throat to macro-reservoir, significantly improves the prediction accuracy of high-quality reservoir, and provides reliable technical support for compact oil and gas reservoir exploration and development.

This invention provides a method for igneous rock facies classification and prediction based on multi-physics discriminant factors, relating to the field of oil and gas field exploration and development technology. The method includes: S1: Constructing a multi-dimensional facies classification model based on diagenesis, integrating lithology index and structural maturity index to quantitatively classify geological facies; S2: Performing principal component analysis on well logging curves to select sensitive well logging curves and construct a sensitive well logging dataset; S3: Constructing rock physical facies factors through Fisher discriminant analysis; S4: Projecting known facies samples onto the rock physical facies factor space, training a classification model using a support vector machine algorithm, and generating a facies identification map; S5: Substituting target well data into the model to complete single-well facies identification; S6: Establishing the correlation between rock physical facies factors and seismic elastic parameters, inverting the seismic data volume into a three-dimensional attribute volume of rock physical facies factors based on a Bayesian inversion framework, fusing them to generate a three-dimensional facies model, thus realizing facies prediction from well point to three-dimensional space.

This invention relates to the field of diagenetic mineral dating technology, specifically disclosing a method for determining diagenetic time under the constraint of laser in-situ U-Pb isotope dating. Using laser in-situ U-Pb isotope dating as its core, the method achieves diagenetic time determination and geological application in three steps. The first step involves sample preparation, target area location, and setting an analysis sequence including background sampling and sample ablation. Single-point or multi-point analysis of the target mineral is performed, and key signals are monitored to obtain reliable U-Pb isotope data. The second step, based on the obtained raw data, involves background subtraction, ratio calculation, standard sample correction, and apparent age calculation. Data harmony is evaluated using charts to determine the diagenetic age and its error. The third step integrates the multi-dimensional age data obtained in the previous step, combined with petrological and burial history data, to establish a diagenetic event sequence, pinpoint the timing of diagenetic processes, and clarify the key period of effective porosity development, providing time constraints for reservoir evaluation and hydrocarbon migration analysis.

The application provides a reservoir quality prediction method based on a "top-slope-depression" superimposition process analysis, and relates to the technical field of oil and natural gas exploration and development; including the following steps: S1, analyzing the present structural characteristics of a target reservoir according to seismic data; S2, restoring a balanced profile, and analyzing the structural evolution process experienced by the reservoir since deposition; S3, analyzing the open and closed evolution processes of the reservoir diagenetic geochemical system according to the "top-slope-depression" superimposition process of the reservoir; S4, determining the diagenesis under different geochemical systems; S5, reservoir quality classification evaluation and spatial distribution prediction. The application uses seismic data to analyze the information of unconformity, overlying strata, burial depth and the like, analyzes the structural / geochemical system evolution process, predicts the distribution law of reservoirs of different levels, and solves the problems of reservoir distribution and pre-drilling prediction under the background of multi-period structural superimposition of deep old layer series.