135 results about "Caprock" patented technology

The invention relates to a non-linear seepage experiment method for gas breaking through a cover layer based on dark field imaging. The method comprises the following steps: placing a microfluidic rock chip on an objective table of a dark field scattering microscope; the injection end of the microfluidic rock chip is connected with a fluid injection module, and the outlet end of the microfluidic rock chip is connected with a downstream outflow pipeline; injecting the formation water solution into the micro-fluidic rock chip until the micro-fluidic rock chip is filled with the formation water solution; opening a gas injection system, and adjusting the dark field scattering microscope until a clear image of a micro-fluidic rock chip pore structure and carbon dioxide displacement formation water is obtained; injecting carbon dioxide with different pressures into the micro-fluidic rock chip, and observing nonlinear seepage migration images of carbon dioxide and formation water in the micro-fluidic rock chip; when it is observed that carbon dioxide migrates to the outlet end of the rock chip, the breakthrough moment is obtained, and the upstream and downstream pressure difference value of the microfluidic rock chip is the breakthrough pressure. According to the method, the nonlinear seepage of the carbon dioxide displacement formation water in the nanopores can be accurately observed, and the breakthrough pressure can be determined.

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 the technical field of model construction, in particular to a geothermal field three-dimensional model construction method based on point cloud data, and the method comprises the steps: synchronously collecting a surface laser radar point cloud, an underground sound wave point cloud and a rock core scanning point cloud, the underground sound wave point cloud comprising signal attenuation coefficient data; performing cover layer signal compensation on the enhanced point cloud data set, inverting a permeability field based on rock core fracture characteristics, and outputting a shadow correction point cloud data set; and inputting the shadow correction point cloud data set into a permeability constraint modeling algorithm to generate a three-dimensional geologic model comprising a heat storage top interface and dynamic permeability distribution. By introducing a three-dimensional voxel modeling method based on point cloud data, the precision and resolution of structural modeling of the heat storage area are effectively improved, an equivalent heat conductivity model for average permeability adjustment and a Darcy flow velocity item are fused, a heat flow evolution equation set refined to a voxel level is constructed, and the modeling precision and resolution of the heat storage area structure are improved. And the depicting capability of the heat flow behavior of the high-temperature gradient region is obviously improved.

The invention provides a safety risk control method for geological storage of carbon dioxide and electronic equipment. A distributed optical fiber sensing system is arranged in at least one injection well of the target sealing and storage area in the axial direction of a shaft and penetrates through a main cover layer and a reservoir; the method comprises the following steps: acquiring background data through a distributed optical fiber sensing system, and establishing a multi-parameter baseline model including a temperature field, a strain field and background noise; temperature, strain and sound wave vibration signals are collected in real time, and key features are extracted; the key features extracted in real time are compared with a preset risk feature library, the types of risk events are identified, and the identified risk events are graded according to the spatial range and intensity of the abnormal signals; and according to the type and the grade of the risk event, generating and executing a corresponding control instruction. According to the embodiment of the invention, the optical fibers are distributed in the whole area along the shaft and the target stratum, a three-dimensional monitoring network covering the sealing body is constructed, and the hysteresis quality of traditional point type measurement and periodic exploration is overcome.

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 discloses a cover rock breakthrough pressure testing device and method based on micro-strain synchronous sensing, and the device integrates a core clamping module, a stress loading module, a temperature control module, a gas injection module, a strain sensing module and a flow monitoring module. Interference of gas displacement water on gas breakthrough identification is eliminated by adopting a multiphase flow isolation design, an optical fiber layout architecture is innovatively proposed to solve the problem of signal interference in traditional rock core gas breakthrough monitoring, and a dynamic uniform temperature field with a gradient compensation function is constructed in combination with a distributed temperature control array embedded in a holder. The breakthrough of gas from the rock core is captured in real time by using the micro-strain signal evolved by gas pressure induction, the breakthrough of the gas can be monitored in the first time, and the testing precision of the breakthrough pressure is improved. The method breaks through the limitation of traditional rock core specifications, can make full use of irregular broken rock samples, successfully solves the test bottleneck caused by insufficient on-site coring integrity, and expands the engineering application boundary of a cap layer sealing performance evaluation technology.

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.

The present application relates to a kind of carbonate buried hill oil reservoir reconstruction gas storage evaluation method and device, the method comprises: the cap rock sealing property and fault sealing property of carbonate buried hill oil reservoir are evaluated, and the trapping sealing property evaluation result is obtained;Attribute data body is obtained by multi-window dip scanning to time domain seismic data, and based on attribute data body, coherent attribute body, curvature attribute body and ant body attribute body are generated, and coherent attribute body, curvature attribute body are respectively fused with ant body attribute body, and the favorable reservoir characterization result is obtained;Reservoir space in the oil-gas-water three-phase saturation under the condition of reconstruction gas storage is calculated, and the capacity parameter evaluation result is obtained;Based on the trapping sealing property evaluation result, favorable reservoir characterization result and capacity parameter evaluation result, buried hill oil reservoir reconstruction gas storage evaluation result is generated.The present application method is suitable for the evaluation of reservoir type reconstruction gas storage, and provides good technical support for the design of gas storage scheme.

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 relates to a salt structure identification method and system based on a seismic wave velocity structure and anisotropy, and belongs to the field of oil and gas resource exploration. The method comprises the following steps: carrying out micro-seismic identification and seismic phase arrival time pickup processing on continuous natural seismological observation data; inversion is carried out on a natural seismic data set obtained through microseismic recognition and seismic phase arrival time pickup processing by using a tomography method containing anisotropy; and identifying the position and form of the salt structure based on the three-dimensional wave velocity structure and anisotropic distribution of the block obtained by inversion and the average wave velocity value of the gypsum salt layer of the block. According to the method, the underground velocity structure and anisotropy are obtained by using continuously recorded natural seismic signals, and the position and form of the salt structure can be judged according to the velocity and deformation difference between the salt structure and the surrounding rock and the cover layer. The key result is crucial to regional structure analysis and searching for favorable oil and gas structures.

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 discloses a method for determining the fault sealing property of CO2 geological storage and a related device, specifically determining whether the lithology of the cap rock corresponding to the reservoir composed of CO2 meets preset conditions, the preset conditions including that the lithology is shale and the proportion of clay minerals meets a preset range; when the lithology of the cap rock does not meet the preset conditions, calculating the difference in displacement pressure between the fault formed between the cap rock and the reservoir and the reservoir; when the difference in displacement pressure is not greater than zero, determining the cap rock thickness, reservoir thickness and fault throw based on the fault profile, and determining the fault sealing property of CO2 geological storage based on the numerical ranking relationship of the cap rock thickness, reservoir thickness and fault throw, the fault sealing property includes: complete fault sealing, partial fault sealing and no fault sealing, and finally determining the fault sealing property of CO2 geological storage.

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 provides an exploration area prediction method and device based on multistage sublithofacies paleogeography, and the corresponding method comprises the steps: constructing a lithofacies paleogeography evolution process in space according to the construction activity property of a same-sedimentary-period area; wherein the space level comprises regional multi-plate blocks, basins in the plates and structure-lithofacies zones in the basins; in time, the lithofacies paleogeography evolution process is restrained according to global sea level change, tectonic settlement, material source supply and climate change; wherein the time level comprises a second-level sequence, a third-level sequence and a fourth-level sequence; and generating a lithofacies paleogeographic map according to the constrained lithofacies paleogeographic evolution process, and predicting a favorable exploration area according to the lithofacies paleogeographic map. According to the method, the development and configuration relation of reservoir forming elements such as hydrocarbon source rocks, reservoir bodies and cap strata in the petroliferous basin is well revealed, so that the oil and gas exploration field and direction are explained, and a basis is provided for optimizing zones and targets.

The invention belongs to the technical field of oil-gas exploration and development and cover rock evaluation, and particularly relates to a method and system for influencing a cover rock natural gas diffusion coefficient relation. The method comprises the steps that influence factors are determined, and multiple groups of different formation water are configured according to the influence factors; taking a to-be-tested cover layer sample, and performing a mixing test on the to-be-tested cover layer sample and the multiple groups of formation water to obtain target experimental data; and determining the influence relationship between the natural gas diffusion coefficient of the to-be-tested cover layer sample and the influence factor according to the target experimental data. According to the method, by determining the influence degree of the formation water with various salts and different mineralization degrees on the cover layer diffusion coefficient, the cover layer diffusion coefficient under the salinized formation water condition is further obtained, and the method has important practical significance on cover layer sealing performance evaluation and oil and gas reservoir preservation condition research.

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.

This invention discloses a method and system for quantitative classification and ranking of exploration zones. The method includes: acquiring source rock data, reservoir data, and caprock data corresponding to each exploration zone; determining the oil source index corresponding to each exploration zone based on the source rock data; determining the reservoir index corresponding to each exploration zone based on the reservoir data; determining the caprock index corresponding to each exploration zone based on the caprock data; determining a preset classification corresponding to each exploration zone based on the oil source index, reservoir index, and caprock index; and ranking each exploration zone based on the ranking information corresponding to each preset classification and the oil source index, reservoir index, and caprock index corresponding to each exploration zone. This invention quantitatively classifies and ranks exploration zones based on source rock data, reservoir data, and caprock data, thereby improving the accuracy of exploration zone classification and ranking results and enhancing the effectiveness of exploration deployment.

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 relates to a thermal effect-considered numerical simulation analysis method for mechanical integrity of a cover layer of a middle-deep gas storage. Three-dimensional numerical reservoir simulation modeling is carried out by taking a reservoir stratum and a cap stratum as a whole, the reservoir stratum and the cap stratum in the model are divided into two large seepage areas by using a method of setting a seepage barrier, so that gas, oil and water seepage transportation and formation pressure conduction do not occur between the reservoir stratum and the cap stratum, and the reservoir stratum and the cap stratum are subjected to three-dimensional numerical reservoir simulation modeling by setting heat transfer parameters. Cover layer temperature changes caused by cold air injection into the reservoir in the gas storage injection-production process can be achieved, and the influence of the heat effect on the reservoir and cover layer ground stress and mechanical integrity is accurately considered. According to the method, a new index, namely a tension safety index with a normalization characteristic, is adopted, dynamic minimum horizontal principal stresses, obtained through numerical simulation calculation, of different time points in the gas storage injection and production process are combined, the cover layer tension damage risk is accurately and quantitatively evaluated, and the gas storage cover layer mechanical integrity risk is more accurate and conforms to the actual stratum condition.