102 results about "Caprock" patented technology

The invention provides a method for preferably selecting a shale gas structure storage favorable area not based on formation pressure. The method comprises the steps that a target research area is selected, and a core exploration target layer series is determined; on the basis of a target stratum shale gas preservation mechanism, core parameters independent of stratum pressure data are screened, and a comprehensive evaluation index system containing target stratum self-sealing performance, regional cover stratum conditions and structural transformation action parameters is constructed; spatial distribution analysis is carried out on each parameter, grading is carried out according to geological laws and adjacent region experience, and weight coefficients are distributed according to the influence degree of the parameters on storage conditions; obtaining a comprehensive score of the structure storage condition of each evaluation unit through grade assignment and weighted stacking calculation; and delineating a shale gas structure storage favorable area according to the comprehensive score. The method is suitable for low-exploration-degree areas with complex structures, sparse drilling wells or lack of formation pressure data, and has the advantages of objective evaluation, high operability and high practical value.

The invention relates to a fault development gas storage operation upper limit pressure determination method considering an overpressure operation condition. The method comprises the following steps: 1, establishing a gas storage three-dimensional geomechanical model covering reservoir, cap strata and peripheral faults; 2, carrying out geomechanical simulation; 3, determining the shear failure resistance limit pressure bearing capacity and the tensile failure resistance limit pressure bearing capacity of the cover layer; 4, designing a gas logging permeability test experiment of the cover rock under different static confining pressures; 5, determining the gas breakthrough pressure of the cover rock under different pressure increasing coefficients; 6, determining the sealing limit pressure-bearing capacity of the capillary tube of the cover layer; 7, determining the anti-slip activation limit pressure bearing capacity and the anti-expansion fracture limit pressure bearing capacity of the fault; and 8, the operation upper limit pressure of the gas storage is determined. According to the method, the four-dimensional geomechanical model is established, the stress path of the reservoir building and gas injection process of the oil and gas reservoir is obtained through numerical simulation, and the dynamic horizontal principal stress of the reservoir building and gas injection process is calculated and determined by taking the determined reservoir top horizontal principal stress as the reference.

The invention discloses a carbon sequestration leakage state evaluation method and device, and relates to the field of carbon sequestration, and the method comprises the steps: obtaining the injection data corresponding to carbon dioxide, and the injection data comprises at least one of the following: the injection speed, the injection pressure, the injection position, and the injection quality; on the basis of a target prediction model, according to the injection data, the sealing damage state of a shaft, the sealing damage state of a cover layer and the sealing damage state of a fault are predicted, and the shaft, the cover layer and the fault are used for sealing the carbon dioxide; and predicting the leakage state of the carbon dioxide according to the sealing damage state of the shaft, the sealing damage state of the cover layer and the sealing damage state of the fault. By adopting the technical scheme, the problem that the prediction efficiency and accuracy of the leakage state of the carbon dioxide are relatively low is solved.

The invention discloses a rapid comprehensive survey method and system for natural hydrogen resources, and the method comprises the steps: rapidly delineating a prospective area through remote sensing and geochemical measurement, fusing aviation gravity and magnetism, earthquake, time-frequency electromagnetism and ground geological survey multi-source data, finding out the characteristics of hydrogen source rock, a migration channel, a reservoir stratum and a cover stratum through the integrated evaluation of source-communication-storage-cover, and carrying out the comprehensive survey of the natural hydrogen resources. A target area is optimized through multi-information fusion, drilling verification is carried out, and efficient exploration of natural hydrogen resources is achieved. According to the method, the potential of the natural hydrogen resource can be rapidly and accurately evaluated.

The invention provides a carbon dioxide geological sequestration project feasibility analysis method and device. The method comprises the steps that stratum rock mechanical parameters, reservoir geological parameters, cover stratum geological parameters, geological stability data and carbon dioxide injection parameters of a carbon dioxide geological sequestration area are obtained; carrying out sealing feasibility analysis based on the reservoir geological parameters, the cover layer geological parameters and the geological stability data to obtain a sealing feasibility analysis result; performing stratum injectability analysis based on the stratum rock mechanical parameters and the carbon dioxide injection parameters to obtain a stratum injectability analysis result; performing earth surface deformation quantity prediction based on the stratum rock mechanical parameters and the carbon dioxide injection parameters to obtain an earth surface deformation quantity prediction result; and performing carbon dioxide geological sequestration engineering feasibility analysis based on sequestration feasibility analysis results, stratum injectability analysis results and surface deformation quantity prediction results. According to the scheme, the feasibility of the carbon dioxide geological sequestration project can be accurately analyzed and evaluated.

The invention provides a rock mechanics dynamic analysis method, system and equipment based on numerical simulation, and relates to the technical field of rock mechanics analys.The method comprises the steps that a three-dimensional geologic model and a three-dimensional geomechanical attribute model of a target sequestration body are constructed; based on the three-dimensional geologic model, establishing an oil reservoir numerical simulation model of the CO2 injection and storage process, and simulating to obtain a reservoir pressure field and a CO2 saturation field under different time steps; carrying out dynamic rock mechanics calculation to obtain dynamic fracture pressure fields of the cover layer under different time steps; and coupling the reservoir pressure field, the CO2 saturation field and the dynamic fracture pressure field, and carrying out transverse and longitudinal leakage risk dynamic evaluation. The technical problems that in the prior art, a simplified geologic model or a coarse mesh model is generally adopted, complex geologic and mechanical characteristics cannot be accurately described, the long-term stability of the storage body cannot be accurately evaluated, and the safety and long-term stability of storage are affected are solved.

This invention discloses a test site and method for evaluating the geological storage capacity of carbon dioxide. The test site includes a brine pool and a brine layer and caprock structure located within the pool. The caprock structure is vertically positioned below the brine layer, and a brine reservoir structure is located below it. The brine reservoir structure is connected to a brine storage tank via a simulated extraction well pipe. The brine storage tank is connected to the brine layer via a simulated injection well pipe. Carbon dioxide is injected into the brine reservoir structure via a simulated gas injection well pipe. Pressure sensors installed on the inner wall of the brine pool monitor the pressure within the brine layer and the brine reservoir structure. The carbon dioxide injection rate, brine extraction rate, and brine injection rate are adjusted based on the monitored pressure to achieve pressure balance between the brine layer and the brine reservoir structure. This invention provides a test site for evaluating the geological storage capacity of carbon dioxide under actual site conditions.

The application discloses a geothermal caprock evaluation modeling method and belongs to the technical field of geothermal resource exploration. In view of the problems that existing caprock evaluation standards are uneven, subjective and lack of quantitative coupling of structural factors and calibration of measured data, the application firstly acquires caprock physical properties and structural data; secondly, a single-factor evaluation model based on physical mechanism is constructed for lithology, thickness, permeability and thermal conductivity; on this basis, a structure-mechanical-integrity coupling model is constructed, which includes basic structure scores, fracture risk indexes and plastic self-repairing capacity factors; finally, by using observation data such as historical breakthrough pressure and leakage events, key parameters in the above model are calibrated through regression and Bayesian methods. The method forms a unified and portable caprock evaluation basic model system, reduces subjectivity, and improves the stability and interpretability of the evaluation results.

The application discloses a method for identifying the dispersion mode of oil and gas through a cap layer, and relates to the technical field of oil and gas reservoirs. The technical scheme is as follows: selecting a rock sample, carrying out particle fluorescence testing, and obtaining a parameter QGF-E representing the content of hydrocarbon adsorbed on the outside of a mineral particle and a parameter QGF-index representing the content of hydrocarbon in the inside of the mineral particle; identifying the dispersion mode of oil and gas through the cap layer according to the relationship between QGF-E and QGF-index, wherein if QGF-E is positively correlated with QGF-index, it indicates that the dispersion mode of oil and gas through the cap layer is slow percolation; and if QGF-index basically remains unchanged with the increase of QGF-E, it indicates that the dispersion mode of oil and gas through the cap layer is episodic rupture. The analysis and testing data obtained through the quantitative fluorescence testing of the cap layer are used to distinguish the dispersion mode of oil and gas through the cap layer by using the quantitative fluorescence data of the cap layer, so that the dispersion mode of oil and gas through the cap layer can be accurately identified, and the problems of randomness and multiple solutions in the prior art can be effectively avoided.

The invention discloses a method and system for evaluating the dynamic brittleness of an underground gas storage, and the method comprises the steps: carrying out an indoor experiment on a cover rock sample, and obtaining a dynamic brittleness-plasticity characteristic containing a rock fatigue damage state; forming a static brittle-plasticity curve based on the logging curve of the sampling well; homing the sampling depth in the static brittle-plasticity curve, and constructing a mathematical correlation model representing two brittle-plasticity relationships through dynamic and static brittle-plasticity characteristics under different sampling depths; based on pre-stack seismic data of the underground gas storage where the sampling well is located, a static brittle-plasticity data body is obtained, and the static brittle-plasticity data body is converted into a dynamic brittle-plasticity data body through the data association model. According to the invention, the three-dimensional dynamic brittle-plasticity attribute of the cap layer can be obtained.

The invention provides a carbon dioxide leakage blocking method and system based on points, lines and planes, and the method comprises the steps: when carbon dioxide leakage occurs, if a fault does not exist in a preset range of the periphery of a drilling well and a cover layer is above a target layer where the drilling well is located, judging that point leakage occurs, and if a fault exists in a certain range of the periphery of the drilling well, judging that point leakage occurs; if no fault exists in a certain range of the periphery of the drilling well, line leakage is judged, and if no fault exists in a certain range of the periphery of the drilling well and the upper portion of the target stratum where the drilling well is located is a non-cover stratum, face leakage is judged; according to the judgment result, selecting a preset plugging scheme to perform carbon dioxide leakage plugging; wherein the preset plugging scheme comprises a point leakage plugging scheme, a line leakage plugging scheme and a surface leakage plugging scheme. According to the technical scheme, leakage blocking can be accurately and efficiently achieved, and the pertinence and effectiveness of blocking are improved.

A method for evaluating the sealing performance of caprock in an underground compressed flue gas energy storage system. The method comprises: acquiring basic properties corresponding to caprock in an underground compressed flue gas energy storage system and sub-properties; acquiring parameters corresponding to all the sub-properties; on the basis of the basic properties and all the sub-properties, constructing a sealing performance evaluation index system table of the caprock in the underground compressed flue gas energy storage system; on the basis of the sealing performance evaluation index system table of the caprock in the underground compressed flue gas energy storage system, constructing a corresponding determination matrix, so as to determine basic property weights and sub-property weights; on the basis of the parameters, determining scores corresponding to the sub-properties; on the basis of the basic property weights, the sub-property weights and the scores corresponding to the sub-properties, calculating a total score of the sealing capability of the caprock in the underground compressed flue gas energy storage system; and on the basis of the total score, determining a sealing performance level of the caprock in the underground compressed flue gas energy storage system, thereby making the evaluation of the sealing performance of the caprock more accurate.

The present application belongs to the technical field of oil exploration, and discloses a method for evaluating the development degree of sand-mudstone reservoir-cap assemblage, which specifically comprises the following steps: conducting regional data analysis for a study area, and mastering the core / cuttings data, logging data and oil testing and production testing data of drilled wells, as well as the seismic data and seismic interpretation horizon data of the whole work area; conducting pre-stack deterministic inversion based on Zeoppritz equation to obtain the data body of the ratio of P-wave velocity to S-wave velocity in the work area; extracting the numerical value of the ratio of P-wave velocity to S-wave velocity along the sandstone layer interpreted by the seismic data to obtain the plan view of the sandstone reservoir; extracting the numerical value of the ratio of P-wave velocity to S-wave velocity along the mudstone layer interpreted by the seismic data to obtain the plan view of the mudstone cap rock; quantifying the relative development degree of the reservoir-cap assemblage by a development degree index calculation formula, constructing the plan view of the development degree index of the sand-mudstone reservoir-cap assemblage, and quantitatively dividing the development degree of the reservoir-cap assemblage. The present application can clearly define the development range of high-quality reservoir-cap assemblage, delineate the favorable exploration area, and further guide the well site deployment of exploration wells.

According to the method for predicting the dynamic breakthrough pressure of the gas storage provided by the embodiment of the invention, the breakthrough pressure of one cover rock core is tested, so that the breakthrough pressure of the gas storage under different operation pressure conditions can be quickly obtained. The embodiment of the invention has the advantages of more accurate breakthrough pressure prediction result, rapid calculation, small experimental test workload and the like, is suitable for scenes of rapid evaluation of working conditions of the breakthrough pressure of geologic body cap strata of gas reservoirs, gas reservoirs, oil reservoirs and the like, and fills the industry blank of rapid acquisition of the dynamic breakthrough pressure field of the cap strata.

The invention discloses a method for calculating the maximum safe injection pressure of geological storage of carbon dioxide in a deep saline water layer, which comprises the following steps of: establishing a three-dimensional geomechanical model; the output parameters are overlying stress distribution and maximum horizontal principal stress distribution of a three-dimensional stress field under the initial formation fluid pressure field and minimum horizontal principal stress distribution under the initial formation fluid pressure field; gradually increasing the initial formation fluid pressure field to pressure fields of a plurality of simulation working conditions, and respectively obtaining minimum horizontal principal stress distribution and overburden stress distribution under the pressure fields of the plurality of simulation working conditions; determining the fracturing critical pressure of the cap layer; determining the activation pressure of a target fault at the cover layer; and determining the maximum safe injection pressure of the geological storage of the carbon dioxide in the deep saline water layer according to the critical pressure of fracture of the cover layer and the activation pressure of the target fault at the cover layer.

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.

According to the embodiment of the invention, a pre-obtained test result of the breakthrough pressure of a rock core is utilized to predict the dynamic breakthrough pressure of a cap layer to hydrogen; according to the method for predicting the hydrogen breakthrough pressure of the cap layer, the dynamic breakthrough pressure of the cap layer to the hydrogen does not need to be repeatedly tested, and the dynamic breakthrough pressure of the cap layer to the hydrogen can be rapidly and accurately predicted only by utilizing the breakthrough pressure of the existing rock core and processing the breakthrough pressure of the existing rock core through the method for predicting the breakthrough pressure of the cap layer to the hydrogen provided by the embodiment of the invention; according to the embodiment of the invention, the change rule of the hydrogen breakthrough pressure of the cap layer along with the hydrogen storage pressure and the hydrogen storage time of the cap layer is found, and the blank of lack of the cap layer sealing performance evaluation method in the underground hydrogen storage field of hydrogen is filled.

The invention discloses a sedimentary basin well-free area earth heat flow prediction method, device and equipment, and the method comprises the steps: determining the thickness of each stratum layer of a sedimentary basin well-free area based on seismic data, a sedimentary cover layer, a base structure and earth crust layering features; determining the rock heat generation rate of the sedimentary cap layer and the wrinkled substrate based on the rock core sample and / or natural gamma logging data of the basin mature exploration area; based on the seismic longitudinal wave velocity, determining rock heat generation rates of the lower earth crust and the middle earth crust; determining the rock heat generation rate of the upper earth crust based on the rock heat generation rate of the wrinkled substrate and the rock heat generation rate of the middle earth crust; based on the valance heat flow values of the upheaval area and the depression area of the basin mature exploration area and the structural evolution characteristics of the basin where the sedimentary basin well-free area is located, determining the valance heat flow of the sedimentary basin well-free area; according to the method, a new thought is provided for finely depicting the current ground temperature field characteristics of the sedimentary basin well drilling deficient region.

This application relates to the field of geological structural analysis technology, specifically to a method, apparatus, and electronic equipment for determining the stage of horizontal slip distance. It solves the problem in existing technologies that the horizontal slip distance cannot be quantitatively calculated in stages during the development stages of overlying en echelon normal faults and underlying vertical strike-slip faults. First, the layering characteristics of the strike-slip fault profile in the area to be measured are determined based on 3D seismic data. Then, based on the layering characteristics of the strike-slip fault profile, the main active stratigraphic system of the strike-slip faults in the area is determined. Finally, the planar distribution of the underlying vertical strike-slip faults and overlying en echelon normal faults in the caprock-draggered strike-slip fault is determined based on relevant attribute maps. Based on this, and combined with the formation theory of overlying en echelon normal faults in caprock-draggered strike-slip faults, the inherent relationship between the cumulative fault displacement of the en echelon normal faults and the horizontal slip distance of the strike-slip fault is used to achieve quantitative estimation of the staged horizontal slip distance of multi-stage active caprock-draggered underground strike-slip faults.

The invention belongs to the technical field of petroleum and natural gas underground gas storage engineering, and relates to a gas storage stability evaluation method based on a crack crossing prediction model, which comprises the following steps: characterizing the built-in crack form and spatial distribution characteristics of a gas storage-cover layer system, and determining the relative position relationship between cracks and boundaries; the method comprises the following steps: acquiring related rock mechanical parameters of a gas storage-cover layer system through indoor experiments and well logging, and determining the distribution type of mean values of different rock mechanical parameters through Bootstrap resampling; performing Monte Carlo simulation according to the distribution type of the rock mechanical parameter mean value to determine the distribution range of typical values of different rock mechanical parameters; according to a Charles law and a Griffith model, establishing a crack crossing prediction model; the rock mechanical parameters are substituted into the crack crossing prediction model, the long-term expansion trend of cracks in the gas storage is calculated, and evaluation indexes of the long-term stability of the gas storage are established to conduct grading evaluation on calculation results.

The embodiment of the invention discloses a carbon dioxide injection pressure determination method and device based on carbon sequestration. The method comprises the following steps: determining reservoir closing pressure of a target reservoir; calculating a first breakthrough pressure of the carbon dioxide on the saturated formation water cover layer; according to the first breakthrough pressure and the reservoir stratum pressure on the upper portion of the target cap stratum, the cap stratum capillary closing pressure upper limit is calculated; and determining a carbon dioxide injection pressure upper limit according to the reservoir closing pressure and the capping capillary closing pressure upper limit. According to the scheme, it can be guaranteed that the carbon dioxide injection pressure does not exceed the reservoir closing pressure and does not exceed the upper limit of the capping layer capillary closing pressure, the determination precision of the carbon dioxide injection pressure is improved, and carbon dioxide leakage is reduced.

The application provides a method and device for evaluating fault-controlled geothermal reservoir resources, and the method comprises the following steps: obtaining the element content of soil on the surface of an exploration area and the element content in water samples; determining the heat source element content, the channel element content, the caprock element content and the reservoir element content according to the element content of soil and the element content in water samples; and evaluating the fault-controlled geothermal reservoir resources of the exploration area according to the heat source element content, the channel element content, the caprock element content and the reservoir element content. The application identifies and selects soil elements closely related to four elements, i.e. heat reservoir, caprock, channel and heat source, in fault-controlled geothermal exploration, and uses soil element indexes and parameters to identify and evaluate the properties of fault-controlled geothermal high-temperature, medium-temperature and low-temperature resources, so as to determine the favorable area of geothermal heat source and heat reservoir.

The invention discloses a carbon dioxide geological sequestration simulation device and method, and belongs to the technical field of carbon sequestration simulation. The carbon dioxide geological sequestration simulation device comprises a model box, a simulation reservoir is arranged on the lower layer in the model box, and a simulation cover layer is arranged on the simulation reservoir; the carbon dioxide solution injection module is used for injecting a carbon dioxide solution into the simulated reservoir; the discharged liquid collecting module is used for collecting discharged liquid of the simulated reservoir; the temperature control module is used for controlling the temperature of the model box; the centrifugal module is used for providing gravitational acceleration for the model box; and the data acquisition module is used for detecting and acquiring changes of temperature parameters and pressure parameters of the simulated reservoir and the simulated cover layer. The simulation device provided by the invention simulates the geological storage of carbon dioxide, can observe the change conditions of a carbon dioxide solution in a reservoir and a cover layer under different years, different temperatures and different pressures, and provides support for long-time geological storage of carbon dioxide.

The invention discloses a method and a system for evaluating the mechanical sealing property and the pressure-bearing capacity of a gas storage. The method comprises the following steps: acquiring breakthrough pressure data of each cover rock sample in the gas storage in a research area; according to the breakthrough pressure data, the upper limit of the breakthrough pressure of the gas storage cover layer is determined; obtaining the thickness of each cover layer of the gas storage in the research area; according to the shale content data of the gas storage in the research area, obtaining a gas storage fault plugging lower limit; taking the upper limit of the breakthrough pressure of the gas storage cap layer as a model numerical simulation condition to obtain a lower limit of fault stability; wherein the gas storage overburden breakthrough pressure and the thickness of each overburden serve as overburden sealing performance evaluation indexes, and the gas storage fault plugging lower limit and the fault stability lower limit serve as fault sealing performance evaluation indexes. Based on the data processing flow, the invention aims to solve the problem of sealing evaluation of the gas storage in the pressurization and expansion process, and provides scientific basis and technical support for safe operation of the gas storage.

This invention discloses a low-cost thermally activated pressure-controlled development method and system for improving the recovery rate of shallow gas in offshore areas. It relates to the field of shallow gas development technology. The method includes: deploying horizontal heating and water injection channels at the bottom, lower part, or near the outer boundary of the shallow gas reservoir; transporting and injecting high-temperature seawater from the sea surface or near the sea surface into the bottom or lower reservoir layer; employing a slow depressurization and pressure window control method in the production well to maintain the reservoir pressure within a range higher than the gas pore connectivity disruption pressure but lower than the caprock breakthrough pressure; installing a variable-diameter sand-control production cylinder in the open-hole production section of the production well; and transporting the developed natural gas to a seabed natural gas hydrate formation shed or container, utilizing the low-temperature, high-pressure environment of the seabed to form natural gas hydrates, thereby achieving low-cost storage and transportation. This invention achieves shallow gas reservoir heating, dissolved gas desolvation, gas-water displacement, pressure control and stable production, and efficient sand control with low energy consumption, thereby improving the recovery rate and economic efficiency of shallow gas development in offshore areas.

The embodiment of the invention discloses a method, device and equipment for determining the operation pressure increasing coefficient of a gas storage and a medium. The method comprises the following steps: constructing a coordinate system by taking a pressure increasing operation index as an abscissa and taking breakthrough pressure and a gas storage pressure increasing coefficient as ordinates at two end points of the abscissa respectively; constructing a relation straight line between the pressure increasing coefficient and the pressure increasing operation index of the gas storage; according to a breakthrough pressure lower limit straight line corresponding to the breakthrough pressure lower limit, a pressure increasing operation lower limit straight line corresponding to the pressure increasing operation lower limit and a relation straight line, determining a pressure increasing operation area, a non-pressure increasing operation area and a non-gas storage cover layer area in the coordinate system to establish a gas storage pressure increasing operation chart; and determining the gas storage pressure increasing coefficient of the mudstone cover layer according to the gas storage pressure increasing running pattern. According to the scheme, the gas storage pressure increasing running pattern can be accurately constructed, so that the gas storage pressure increasing running condition of the target area is evaluated based on the gas storage pressure increasing running pattern, and the gas storage pressure increasing coefficient is accurately determined.

Provided herein are methods and systems for producing carbon-free hydrogen. The method includes introducing a hydrogen sulfide (H2S)-bearing fluid stream into an iron-rich subsurface reservoir predominantly containing one or more types of reactive ferric iron-rich minerals, and contacting the H2S-bearing fluid stream with the one or more types of reactive ferric iron-rich minerals present in the iron-rich subsurface reservoir, thereby generating a sweet fluid stream having a reduced-sulfur content as compared to the H2S-bearing fluid stream and an iron scale deposited within the iron-rich subsurface reservoir and forming a hydrogen gas cap in an upper portion of the iron-rich subsurface reservoir beneath a cap rock seal.

The application discloses a salt cavern cavity forming process control method for compressed air energy storage, and belongs to the technical field of compressed air energy storage.The application solves the problem that, due to dependence on artificial experience and fixed process parameters, the existing cavity forming control method is difficult to accurately control the three-dimensional form of the cavity when facing a non-homogeneous salt rock stratum, and the problem that local over-dissolution, damage to the sealing property of the cap layer of the cavity top and stress concentration of the cavity wall easily occur, affecting long-term stability.The application builds a salt cavity form dynamic inversion model based on real-time sensing of geological parameters, and combines bidirectional coupling simulation of fluid mechanics and rock mechanics to perform closed-loop adaptive optimization control on water injection displacement, dissolving agent cushion thickness and pipe lifting speed, realizes intelligent transformation of the salt cavern cavity forming process from experience driving to data model driving, improves the cavity forming precision, and significantly enhances the construction economy and operation safety of the gas storage.

This invention discloses a method and system for evaluating the sealing performance of caprocks in aquifer reservoirs using a caprock-reservoir assembly. Foamed cement is used to adjust the mix proportions to obtain a transition layer similar in density and porosity to the caprock, serving as a bond between the caprock and reservoir. This system can be applied to caprocks of any lithology, fully considering the initial structural characteristics of the caprock, i.e., using pre-fabricated fractures to fully simulate the complex fractures or faults present in the original caprock. Gas leakage detection of the caprock body is conducted by simulating the cyclic injection and production of gas into the reservoir under simulated formation conditions. Real-time analysis of gas leakage along the caprock body allows for effective evaluation of caprock sealing failures and leakage caused by different types of caprocks and caprocks with different fracture characteristics during the injection and production process of the underlying reservoir. This provides a reference for establishing the upper limit operating pressure of aquifer gas storage facilities with different types of caprocks.

The invention discloses a carbon sequestration area determination method and device, a storage medium and an electronic device, and the method comprises the steps: carrying out the component analysis of underground water data of different geological stratums in a candidate sequestration area, and obtaining the isotope ratio of the same chemical composition, the isotope ratios are generated from chemical compositions and isotopes of the chemical compositions in the groundwater data, the different geological stratums include overground cover stratums and underground reservoirs, and the isotope ratios include a first isotope ratio of the overground cover stratums and a second isotope ratio of the underground reservoirs; according to the ratio change value of the first isotope ratio and the ratio change value of the second isotope ratio, determining the sealing grade of the candidate sealing region; and determining the candidate sequestration area as a carbon sequestration area under the condition that the closure level is determined to be higher than the preset level. By adopting the technical scheme, the problem that the storage area cannot be accurately determined is solved.