770 results about "Carbonate rock" patented technology

An ultra-deep carbonate rock dissolution simulation experiment device and method. The experiment device comprises: at least two reaction kettles (1) arranged in series connection, the reaction kettles (1) each comprising a confining pressure mechanism (10) and an axial pressure mechanism (20), wherein the confining pressure mechanism (10) is provided with a rock core cavity for accommodating a rock core (2) and can apply confining pressure to the rock core (2), the axial pressure mechanism (20) is used for applying axial pressure to the rock core (2) in the rock core cavity, and the axial pressure mechanism (20) is provided with a reaction solution interface communicating with the rock core cavity; a solution pressure vessel system (40), capable of providing a reaction solution and injecting the reaction solution into the rock core cavities by means of the reaction solution interfaces; at least two back pressure control devices (30), outlet ends of the rock core cavities of the reaction kettles (1) being connected to the back pressure control devices (30); and a detection system (50). The rock core cavities of the reaction kettles (1) are in series connection, and the reaction solution provided by the solution pressure vessel system (40) can sequentially flow through the rock core cavities in series connection, and the detection system (50) is used for separately performing detection on each rock core cavity, thereby solving the technical problem of the difficulty in conducting simulation experiments with respect to the dissolution of strongly altered carbonate rocks in ten-thousand-meter ultra-deep conditions.

The invention belongs to the technical field of carbonate rock oil-gas exploration, and particularly discloses a complex carbonate rock logging lithology identification method based on a diffusion model, and the method comprises the following steps: determining the lithology types of a plurality of observation wells based on the on-site rock core observation and slice analysis, and synchronously obtaining the logging data of the corresponding observation wells, constructing a lithology training data set in combination with a depth corresponding relationship between the lithology category and the logging data; a diffusion model is adopted to generate and supplement lithology categories with insufficient samples; logging data is adopted as an input feature, the lithology category is adopted as an output label, and a convolutional neural network fused with a Bayesian optimization algorithm and a Transformer hybrid model are utilized to train a lithology identification model; and inputting to-be-identified logging data into the trained lithology identification model, and outputting a lithology identification result. According to the method, high-precision lithology identification can be realized under the conditions of deep layers and complex stratums.

The invention provides a carbonate reservoir detection method and system based on resistivity anomaly inversion, and relates to the technical field of oil-gas exploration, and the method comprises the steps: obtaining historical data; performing multi-scale analysis and classification processing according to the resistivity data to obtain a resistivity anomaly distribution diagram; carrying out modeling processing according to the geological parameters and the carbonate rock resistance test data to obtain a geological-electrical coupling relation model; a resistivity three-dimensional distribution model is constructed according to the resistivity anomaly distribution diagram and the geology-electrical coupling relation model; performing resistivity prediction processing based on adaptive mesh generation and parallel calculation to obtain a resistivity space distribution prediction result; and performing three-dimensional geological modeling processing according to the resistivity spatial distribution prediction result to obtain an oil and gas reservoir detection result of the target area. According to the method, through multi-scale resistivity anomaly analysis, resistivity data processing is carried out by adopting high-order derivative filtering and wavelet decomposition technologies, and the resistivity anomaly region can be efficiently extracted.

The invention relates to a carbonate reservoir pore structure quantitative characterization method and device, and the method comprises the steps: carrying out the pore structure feature extraction of obtained digital images of different scales of a carbonate reservoir, and obtaining corresponding binary images; aiming at the binary image of each scale, taking at least partial region of the binary image as a target region, and searching and screening the binary images of different scales through a similarity matching algorithm based on the pore distribution feature, the pore change feature, the pore fractal feature and the pore shape feature of the target region to obtain a pore key region; and on the basis of a pre-constructed multi-scale comprehensive fractal dimension function and the pore key areas of different scales, the carbonate reservoir multi-scale comprehensive fractal dimension is obtained through calculation. According to the method, the comprehensive quantitative characterization of the multi-scale pore structure is realized, the problem of relevance and fusion characterization among multi-scale images is solved, and data support can be provided for effectively solving the productivity prediction and evaluation of the carbonate reservoir.

The present disclosure provides a method for evaluating a geological storage amount of carbon dioxide (CO2) in a fractured-vuggy carbonate reservoir, including: performing image identification on a three-dimensional scanned image of a rock sample to obtain identified rock information; inputting the identified rock information to a computational fluid dynamics-based numerical simulator for constructing a fractured-vuggy rock structure model, and obtaining geometric topological information of the rock sample based on the fractured-vuggy rock structure model; inputting relevant parameters of the rock sample and the geometric topological information to a multi-scale multi-phase flow numerical model for numerical simulation of multi-phase flow migration of CO2 in models of different scales and obtaining a multi-scale numerical simulation result; and calculating a multi-scale CO2 storage efficiency based on the multi-scale numerical simulation result. The present disclosure may effectively evaluate and predict the storage capability of CO2 in fractured-vuggy carbonate rock.

This invention discloses a method for indicating the degree of pyrite development in carbonate reservoirs, belonging to the field of geological exploration technology. Its key features include the following steps: a) selecting sensitive parameters to distinguish pyrite development based on the well logging response characteristics of pyrite-developed strata; b) establishing trend lines for the variation of sensitive parameters in formations with no or low pyrite content using these sensitive parameters; c) constructing trend lines for the variation of sensitive parameters with pyrite content based on strata data from key wells with different pyrite contents; d) identifying pyrite-enriched strata in the wells to be identified based on the intersection indications of the sensitive parameters; e) evaluating the degree of pyrite development in the pyrite-enriched strata by assessing the degree of difference in the intersection of sensitive parameters. This invention achieves the identification of pyrite-enriched strata through resistivity and sonic transit time intersection, enabling rapid and accurate identification of the degree of pyrite development in carbonate reservoirs.

The invention belongs to the technical field of micro-fluidic chips, and discloses a real carbonate rock micro-fluidic chip and a preparation method thereof.A binder is poured into a groove in a transparent substrate, then a core slice is placed on the surface of the uncured binder in the groove, and after the binder is cured, the surface of the core slice is ground to obtain the real carbonate rock micro-fluidic chip. Then patterning the surface of the core slice by using laser, and etching a real pore channel image, a liquid injection channel and a liquid outflow channel; covering the surface of the semi-finished product carbonate rock micro-fluidic chip with a PDMS film; the transparent cover plate covers the surface of the PDMS film, the transparent substrate, the PDMS film and the transparent cover plate are fixedly connected, and liquid inlets and liquid outlets are formed in the positions, corresponding to the liquid injection channel and the liquid outflow channel, of the transparent cover plate and the PDMS film. According to the micro-fluidic chip, the real pore channel structure can be restored in the micro-fluidic chip, the mineral characteristics of the real stratum can be restored at the same time, and the visibility of the micro-fluidic chip is not affected.

The invention discloses a phosphogypsum leachate-carbonate rock dynamic corrosion reaction analysis method based on numerical simulation, and aims to research a migration-corrosion coupling mechanism of acid leachate in a carbonate rock fracture network. The method comprises the following steps: firstly, acquiring a two-dimensional image sequence of a rock core sample through CT (Computed Tomography) scanning, carrying out operations such as threshold segmentation, membrane enhancement and a light shading algorithm on an image by utilizing AVIZO software, extracting fracture structure parameters and establishing a high-precision three-dimensional model; then, multiple groups of simplified models with different fracture widths are constructed in COMSOL Multiphysics, a Darcy flow field and a solute concentration field are coupled on the basis of the Darcy law and a dilute matter transfer theory, and the dynamic corrosion effect under the multi-field coupling effect is quantitatively represented by setting hydraulic gradient boundary conditions and chemical reaction kinetic parameters; the dynamic corrosion reaction process of calcium ions, hydrofluoric acid, sulfuric acid and phosphoric acid in the ardealite leachate and carbonate rocks with different crack widths is accurately simulated.

The invention discloses a fracture-vug type carbonate rock fracture-vug reservoir reasoning method and device based on a knowledge graph. The device comprises an ontology construction module, a knowledge extraction module, a knowledge fusion module, a business rule module, a reasoning model module and a reservoir comprehensive evaluation model. Wherein the business rules comprise an oil reservoir analysis rule, a reservoir physical property rule, a logging interpretation rule and the like, the calculation model is a carbonate reservoir comprehensive reasoning model, and comprehensive reasoning analysis is performed on each fracture-cavity reservoir by combining the business rules of the business rule module with a carbonate fracture-cavity reservoir comprehensive reasoning method. And generating a carbonate rock fracture-cavity reservoir optimization scheme. According to the method, the exploration target optimization working efficiency of the carbonate fractured-vuggy reservoir can be improved, the pertinence, accuracy and timeliness of exploration decision making are improved, the exploration risk is reduced, and the decision making efficiency is improved.

The invention discloses a salt lake carbonate rock multi-parameter quantitative classification and reservoir evaluation method, and relates to the technical field of oil-gas exploration. The method comprises the following steps: selecting a key well in an exploration block, collecting a plurality of salt lake carbonate rock samples, preparing an analysis sample under an anhydrous condition, quantitatively measuring a salinity parameter, a mixing index and a diagenesis strength parameter by utilizing the analysis sample, and determining a salinity code, a mixing code and a diagenesis phase code. And naming the salt lake carbonate rock based on the salinity code, the mixed product code and the lithogenous phase code, directly evaluating the salt lake carbonate rock reservoir according to a naming result, and performing single well comprehensive evaluation on the salt lake carbonate rock reservoir. According to the method, the influence of salinity, mixed accumulation and diagenesis strength on formation and evolution of the salt lake carbonate rocks is fully considered, accurate division of the types of the salt lake carbonate rocks is achieved, the reservoir naming result is directly associated with reservoir evaluation, and technical support is provided for standardized evaluation of the salt lake carbonate reservoir.

The invention discloses a method and system for evaluating the permeability of a carbonate reservoir based on nuclear magnetic resonance, and the method comprises the steps: obtaining nuclear magnetic resonance logging T2 spectrum test data and permeability data of the reservoir, and dividing a corresponding training set and a test set; performing data standardization processing on input and output of the training set to eliminate differences of units and orders of magnitude among different input vectors; inputting the standardized training set into a preset deep learning model for training to obtain a permeability calculation model; and testing the performance of the permeability calculation model by using the test set. The calculation precision of nuclear magnetic resonance logging information for evaluating the permeability of the carbonate reservoir is improved, and effective support is provided for reservoir parameter fine evaluation and later oil reservoir development.

The invention provides a double-criterion active learning carbonate rock lithology classification method and system. The method comprises the steps of obtaining conventional logging information of multiple wells; in the data preprocessing step, a logging curve is intercepted into sample segments, and data are made to conform to the input shape of the model; building a hybrid model Bi-LSTM-DANN combining a bidirectional long-short term memory neural network and a domain adversarial neural network, and inputting the intercepted samples into the network; domain adversarial pre-training: defining a loss function to determine hyper-parameters and training the network to obtain a pre-training model; the active learning fine tuning adopts a dual-criterion active learning method combining KMeans and a minimum confidence method, and the network is further fine-tuned to obtain a final model; and testing and applying the model. According to the method, two sample query strategies are fused, so that the prediction performance of the model is greatly improved; the performance of the model is further improved through domain confrontation, accurate identification of the lithology of the carbonate rock is achieved, and the system has good mobility and robustness.

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.

A method for hydrocarbon production from a carbonate formation includes receiving a carbonate texture description of a drill cutting. A pre-defined grain fraction is assigned to the drill cutting based on the texture description. The pre-defined grain fraction is one of a set of pre-defined grain fractions and each pre-defined grain fraction of the set of pre-defined grain fractions corresponds to a respective one the set of carbonate texture descriptions. Based on the pre-defined grain fraction assigned to the drill cutting and a depth of the wellbore from which the drill cutting is taken, an estimated porosity of the drill cutting is determined using an algebraic equation, coefficients for which are determined by regression analysis using reference rock samples that have been assigned pre-defined grain fractions from the same set of pre-defined grain fractions.

A carbonate rock rough slit acid liquid mass transfer coefficient calculation method comprises the following steps: 1) setting conditions based on carbonate rock rough morphology, and constructing a diffusion boundary layer thickness equation under the rough morphology conditions; and 2) solving to obtain the thickness of the diffusion boundary layer, and calculating the mass transfer coefficient according to the relational expression between the thickness of the diffusion boundary layer and the mass transfer coefficient. The carbonate rock rough slit acid liquid mass transfer coefficient calculation method is provided by considering rough morphology influence, no slippage of the acid liquid and filtration loss, and compared with a plane assumption condition in the prior art, the method is more consistent with a real condition, and the coincidence degree with an experimental test result is higher.

The invention provides a carbonate rock lithology identification method based on machine learning, and the method comprises the steps: obtaining the hyperspectral data of a carbonate rock sample through an ASD spectrometer, and carrying out the preprocessing of the hyperspectral data; a mixed feature selection method is adopted, firstly, feature wavebands in the hyperspectral data are selected, then a random forest method is adopted for feature importance sorting, and features with high importance are selected; constructing a carbonate rock lithology identification model based on the selected features, wherein model parameters are determined by a machine learning algorithm; and predicting the mineral content in the carbonate rock according to the lithology identification model so as to identify the lithology of the carbonate rock. According to the method, on the basis of carbonate rock hyperspectral data, feature selection is carried out by adopting a mixed feature selection method after preprocessing, a lithology identification model is established on the basis, model parameters are determined through a machine learning mode, mineral component content is predicted, and therefore carbonate rock lithology identification and classification are achieved. And the identification precision and efficiency are greatly improved.

The invention discloses a carbonate rock physical modeling method, application, a device, equipment and a medium, and belongs to the field of geophysical exploration. The modeling method comprises the following steps: establishing a pore quantitative interpretation template through logging data, determining pore types and pore parameters of various pores, adding the pores into a rock matrix to obtain a dry rock skeleton model, adding a fluid mixture into the dry rock skeleton model, and establishing a carbonate rock physical model; estimating the longitudinal and transverse wave velocities of the rock by using the rock physical model; the invention further provides a device for implementing the method, computer equipment and a computer readable storage medium. According to the method, the problem that the difference of estimation results by using a conventional rock physical model is large due to a carbonate rock multi-pore structure is solved, and meanwhile, the transverse wave estimation information can be quickly and accurately obtained by using the carbonate rock physical model. The method can be applied to rock physical modeling and pre-stack inversion technologies of carbonate rocks.

The invention discloses a fracture-cavity communication probability calculation method and device based on multi-source potential field diffusion conduction, and relates to the technical field of oil and gas reservoir exploration, and the key point of the technical scheme is that the fracture-cavity communication probability is calculated from the spatial distribution and scale of reservoir development of carbonate rocks, the fluid communication channel and fluid storage characteristics in the carbonate rocks, and the formation energy of carbonate reservoirs. The reservoir characteristics of the ultra-deep carbonate rock fracture-cavity body are described in the three aspects, and a multi-source potential field diffusion method is used for calculating a karst cave communication strength body, a fracture communication strength body and an in-fracture net pressure body. According to the method, researchers can be helped to obtain better understanding of connectivity of karst caves, fractures and the like, and particularly for sectionality and well group division of fault zones, the researchers can be helped to predict reservoirs more accurately.

The present invention discloses a method for determining the maximum burial temperature of a formation by using carbonate clumped isotopes. The method provided by the present invention comprises the following steps: collecting formation samples and petrological analysis; testing the carbonate clumped isotope Δ47 of the samples; calculating the clumped isotope temperature T of the samples Δ47 ; preliminarily estimating the range of the maximum burial temperature of the formation where the samples are located; and according to the preliminary estimation result, selecting a solid-state reset model to determine the maximum burial temperature of the formation. The present invention solves the problem that it is difficult to accurately determine the maximum burial temperature for ancient marine carbonate rock formations due to the lack of vitrinite or zircon, reduces the result error, clarifies the applicable scope of the method, improves the feasibility, and has very important significance for the evolution of the organic matter maturity of source rocks and the evaluation of oil and gas resources in this formation series.

The embodiment of the invention relates to a lithologic trap identification method and device, electronic equipment and a storage medium, and the method comprises the steps: carrying out the geologic horizon interpretation according to the seismic data of a target work area, and determining the stratum thickness; extracting at least one seismic fracture attribute in the seismic data, and identifying strike-slip fracture of a target work area according to the at least one seismic fracture attribute; establishing a sedimentary geologic model according to the stratum thickness, the strike-slip fracture and the drilled data of the target work area; carrying out forward modeling based on the sedimentary geologic model, and determining seismic waveform templates corresponding to a reservoir and a lithologic body respectively; determining distribution conditions of different seismic waveforms in the seismic data based on the seismic waveform templates corresponding to the reservoir and the lithologic body respectively; according to the stratum thickness, the strike-slip fracture and the distribution condition of the different seismic waveforms, the lithologic trap of the target work area is identified; and accurate identification of the lithologic trap of the carbonate rock is realized.

The invention provides a water lock removing agent suitable for carbonate rock gas reservoirs and a preparation method thereof.The water lock removing agent suitable for the carbonate rock gas reservoirs comprises, by mass, 1-5% of a wetting reversal agent, 1-5% of a water lock removing agent, 1-5% of a water lock removing agent, 1-5% of a water lock removing agent, 1-5% of a water lock removing agent, 1-5% of a water lock removing agent, 1-5% of a water lock removing agent and the balance water. 5%-25% of a nonionic surfactant; 10-50% of an auxiliary agent; and the balance of water. The wetting reversal agent is a fluorosilicone cationic compound. According to the carbonate rock gas reservoir water block removing agent provided by the invention, the structures of Rf and M groups in molecules are limited by the fluorosilicone cationic compound, so that on one hand, the relatively strong adsorption performance of the agent on the surface of carbonate rock is ensured, and on the other hand, the wetting reversal effect of the agent on the solid surface of the carbonate rock is ensured; and the inner surface of the pore throat is endowed with relatively strong liquid drainage performance, so that the gas phase can be discharged from the pore throat under very small formation driving pressure, the gas phase permeability and the gas well yield are improved, and the stable production period of a gas reservoir is prolonged.

The invention provides a prospecting method for a brine type lithium-potassium-boron ore deposit in a foreland basin carbonate rock stratum. The prospecting method comprises the steps that the type of a metallogenic potential structure unit is determined; determining a mineralization brine supply potential source type; determining the type of a favorable metallogenic structure unit; calculating a construction unit comprehensive evaluation coefficient, and screening favorable exploration construction units; carrying out metallogenic brine carbonate reservoir analysis on the favorable exploration structure unit, and delineating a favorable exploration target area; and performing drilling verification on the favorable exploration target area, and evaluating the economic value of the favorable exploration target area. According to the method, multi-level prospecting prediction from full-basin-scale optimal construction units to local target area fine evaluation is realized, and the exploration efficiency and the success rate of the brine type lithium potassium boron deposit are remarkably improved.

A method for recognizing a dominant carbonate rock reservoir in a complex facies zone, comprising: determining a lithologic type and lithologic physical properties of a study section (S100); carving out a development pattern configuration of a special geologic body in the lithologic type (S200); on the basis of the development pattern configuration, using an iterative modeling method to construct an inversion low-frequency model under a phase controlled constraint (S300); using the inversion low-frequency model to perform multi-parameter pre-stack inversion of the study section to obtain an inversion parameter data volume of the study section (S400); and using a multi-parameter intersection method to predict a dominant reservoir distribution in the inversion parameter data volume (S500). Also provided are an apparatus for recognizing a dominant carbonate rock reservoir in a complex facies zone, and an electronic device. By means of the phase controlled constraint, a configuration attribute representing geomorphic facies and lithologic inversion representing lithologic facies are comprehensively considered, and the attribute lateral resolution and the inversion longitudinal resolution are combined, thereby achieving high-precision recognition of a dominant carbonate rock reservoir in a complex facies zone.

The present invention relates to a method for predicting the breakthrough time of water drive in carbonate oil reservoirs based on an agent model, comprising the following steps: S1: selecting and disclosing a data set of actual production history of a certain oil reservoir; S2: dividing the natural water drive of the oil reservoir into four types of water drive according to the production dynamics of the oil reservoir; S3: using a finite element conceptual model to simulate and calculate the relevant parameters of the oil reservoir to obtain a numerical simulation sample data set; S4: constructing four types of water drive breakthrough time prediction sub-models; S5: constructing a training set of four types of water drive breakthrough time prediction sub-models; S6: training each type of water drive breakthrough time prediction sub-model to finally obtain a trained prediction model; S7: correcting the trained prediction model to obtain a final carbonate oil reservoir water drive breakthrough time prediction model. The use of this technical solution can solve the shortcomings of the existing methods for predicting the breakthrough time of water drive in oil reservoirs, such as long time consumption, poor adaptability and pertinence, and can effectively guide the specific development work of actual oil wells.

The invention discloses a carbonate reservoir fracture permeability test method, and relates to the technical field of ore exploration, the test steps are as follows: S1, blending a tracer agent: preparing iohexol, iopamidol and barium sulfate suspension, and blending to obtain the tracer agent; s2, injecting the prepared tracer agent into the rock stratum, and waiting for diffusion of the tracer agent; s3, a CT scanning device is used for scanning the rock stratum, the flowing path of the tracer agent on the rock stratum is tracked, image data are collected and obtained, and the collected data image is preprocessed; and S4, constructing a three-dimensional model of the crack network by using a three-dimensional imaging technology, displaying a three-dimensional flow path of the tracer agent in the crack, analyzing the acquired CT image data, and measuring to obtain the concentration distribution of the tracer agent at different positions. By means of the tracer agent injection method, the rock stratum fracture permeability closer to the actual situation is obtained, and a more reliable basis is provided for development and evaluation of carbonate rock reservoirs.

The invention provides a method for constructing a geoelectric structure prediction model based on time-frequency electromagnetism, and belongs to the field of oil exploration. The method comprises the following steps: firstly, establishing an initial reservoir model based on a model-driven geophysical inversion process; then geophysical data and a corresponding reservoir model data set are collected, classified and standardized, and construction of the data set is completed; establishing a reservoir geoelectric structure prediction model based on the deep learning model; and finally training the reservoir geoelectric structure prediction model by using the data set to obtain an optimized reservoir geoelectric structure prediction model. Wherein the reservoir comprises an ultra-deep carbonate rock reservoir; the invention further provides a method for constructing the model for predicting the geoelectric structure of the ultra-deep carbonate reservoir. Compared with the prior art, according to the geoelectric structure prediction model constructed by the method, when observation data is input, an inversion result can be obtained without executing an iteration process, and the reservoir oil-water relationship can be further analyzed according to the inversion result.

The present invention provides a carbonate reservoir classification method and a reservoir type identification plate establishment method. The identification plate establishment method includes: obtaining well logging data, core analysis data, pore throat median radius data and oil test data of coring wells for exploration and development of carbonate oil and gas fields; classifying the coring well section reservoirs; for each coring well section reservoir of each reservoir type, calculating the reservoir structure parameters and performing normalization processing; obtaining the intersection diagram of the normalized reservoir structure parameters and porosity to obtain a reservoir type identification plate. The carbonate reservoir classification method includes: using the above method to establish a carbonate reservoir type identification plate for the work area; obtaining well logging data and pore throat median radius data for the target reservoir in the work area; determining the target reservoir structure parameters and performing normalization processing; using the normalized reservoir structure parameters and porosity of the target reservoir to intersect, and referring to the established carbonate reservoir type identification plate for the work area to identify the target reservoir type.

The invention relates to an identification method and system for a hydrothermal alteration zone in carbonate rock construction, and belongs to the field of remote sensing geological prospecting, and the identification method comprises the steps: obtaining and preprocessing a spaceflight hyperspectral remote sensing image of a to-be-identified region, and obtaining surface reflectance data; mineral component analysis is carried out based on the surface reflectance data, carbonate mineral dominant pixels are marked, and a binary mask array after assignment is generated; extracting hydrothermal alteration information and generating an information intensity array according to the assigned binary mask array; performing binarization processing on the information intensity array according to a preset threshold value to generate a binary logic array; and converting the binary logic array into a geographic space vector area file based on an original image geographic coordinate system, and taking the geographic space vector area file as a hydrothermal alteration zone identification result. According to the method, rapid and accurate identification of the hydrothermal alteration zone in the carbonate rock area can be facilitated.

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 petroleum geology experiments, in particular to an experimental simulation and quantitative evaluation method suitable for collaborative evolution of carbonate rock apertures. The method comprises the steps that paleo-temperature, paleo-confining pressure, paleo-axial pressure and paleo-pore pressure evolution paths of a target reservoir are obtained through geological process inversion and converted into experiment loading parameters; preparing a plurality of parallel samples and carrying out initial state multi-scale characterization; in the high-temperature and high-pressure triaxial experiment system, the same temperature-pressure cooperative loading path is applied to the samples under different pore pressure working conditions; carrying out fine comparison analysis on the sample after the experiment; and finally, establishing a reservoir quality evaluation chart by calculating original parameters such as a compaction resistance coefficient, a pore-crack synergistic interaction index and crack communication efficiency. The problems that a traditional experiment is disjointed with the geological process, and multi-field coupling simulation is insufficient are solved, and accurate revelation and quantitative evaluation of the ultra-deep carbonate rock aperture co-evolution mechanism are achieved.