182 results about "Caprock" patented technology

The invention belongs to the technical field of gas storages, and particularly relates to an experimental method and device for evaluating fault stability under injection-production alternating stress of a gas storage. The method comprises the following steps: acquiring reservoir information of a to-be-detected gas storage; making a three-dimensional model according to the reservoir information, and configuring model parameters according to formation water and natural gas initially injected into the three-dimensional model; an injection-production pipe is inserted into the three-dimensional model, the multi-cycle gas injection-production process is simulated, and fault changes in the three-dimensional model are monitored; and optimizing model parameters of the three-dimensional model according to the fault change condition, and determining optimal model parameters. A fault with any dip angle can be simulated, the experimental model comprises a whole geologic body simulating a gas storage, surrounding rocks including a cover layer and a bottom supporting layer and wrapping the periphery of a reservoir body, the reservoir is disconnected by the fault, the contact relation of the two reservoirs can be designed according to the actual condition of the stratum, and an injection-production well is designed in the model. The injection-production well simulates high-speed injection-production of the gas storage.

The invention discloses a CO2 storage multi-field coupling safety evaluation method considering fracture evolution, and relates to the technical field of complex oil and gas reservoir development, and the CO2 storage multi-field coupling safety evaluation method comprises the following steps: s1, constructing and solving a multi-field coupling model; s2, virtual crack grid construction and expansion: according to the updated model stress field parameters, judging whether cracks are generated or not, and if so, constructing and expanding a corresponding virtual crack grid; s3, evaluating the integrity of the cover layer: after each time step is finished, evaluating the integrity of the cover layer; and continuing numerical simulation of the next time step until the simulation is finished. According to the method, comprehensive coupling of multiple physical fields such as crack generation and expansion, CO2 seepage, heat transfer between the injected CO2 fluid and the reservoir and between the injected CO2 fluid and the reservoir fluid, geological stress redistribution and the like in the CO2 storage process is fully considered, so that the spatial and temporal change of each physical field in the reservoir in the CO2 injection process can be truly represented, the simulation precision is greatly improved, and the simulation efficiency is improved. And the uncertainty caused by fixed parameters or simplified processing is effectively reduced.

The invention discloses a construction method of an artificial geological cover layer for carbon dioxide sequestration, and belongs to the technical field of carbon dioxide sequestration. The construction method of the artificial geological cover layer for carbon dioxide sequestration comprises the following steps: determining construction parameters of the artificial geological cover layer; determining the position of an overlying strata artificial geological cap layer in the mining space, and determining the position of an overlying strata key layer by using a key layer discrimination method according to drilling geological data of a mining area; determining the following grouting parameters including arrangement and size of ground grouting holes, proportion and particle size of grouting materials and grouting pressure; grouting is conducted on the artificial geological cover layers with different depths; and CO2 leakage of the artificial geological cover layer is monitored. According to the construction method of the artificial geological cap layer for carbon dioxide sequestration, the CO2 coal mine mining space geological sequestration reserves can be increased, and the application range of the CO2 coal mine mining space geological sequestration technology is wider.

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 discloses a method and a system for predicting the vertical connectivity of a fault in a petroliferous basin, and relates to the technical field of fault connectivity detection.The method comprises the steps of determining a fault vertical connectivity coefficient of a target position according to influence factors of the fault vertical connectivity of the target position; the influence factors comprise the thickness of the fractured cover layer, the shale content, the normal stress of the fault surface, the formation fluid pressure, the brittleness degree of the cover layer and the fault displacement of the fault; the target position is the target position of a non-drilling area in the petroliferous basin; and predicting the vertical connectivity of the target position according to the fault vertical connectivity coefficient of the target position. According to the method, the identification accuracy of the vertical connectivity of the fault in the petroliferous basin is improved.

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.

A method of assessing a caprock for caprock defects comprises drilling a first well into a geologic sequence, the geologic sequence comprising a first subsurface formation, the caprock positioned above the first subsurface formation, and a second subsurface formation positioned above the caprock; sampling subsurface fluids of the geologic sequence for helium concentration within the second subsurface formation, within the caprock, and within the first subsurface formation; drilling a second well into the geologic sequence a pre-determined distance away from the first well; sampling the subsurface fluids for the helium concentration within the second subsurface formation, within the caprock, and within the first subsurface formation through the second well; determining whether a deviation exists between the helium concentration at the first well and at the second well, the deviation indicating the caprock defect is present; and halting further drilling into the geologic sequence upon determining the caprock defect is present.

The invention belongs to the technical field of geological research, and particularly relates to a method for obtaining the prospecting success rate of a prospecting area. The exploration success rate S is determined through the oil source coefficient O, the reservoir coefficient R, the cover layer coefficient C and the trap coefficient T. The prospective area exploration success rate determined by the method truly reflects the actual exploration potential and the drilling risk of the prospective area, and the error between the pre-drilling prediction result and the post-drilling actual result is reduced, so that an effective and accurate prospective area exploration potential evaluation and exploration deployment scheme is obtained.

The invention relates to the field of petroleum and natural gas engineering, in particular to a method for testing the oil and gas storage capacity of a tight sandstone reservoir in the exploration and development process. A tight sandstone reservoir oil and gas reservoir capacity testing method comprises the following steps: acquiring a pressure-time curve of a tight sandstone target reservoir section and an upper cover rock sample thereof; constructing a pressure drop standard function; respectively fitting the pressure-time curve of the target reservoir section rock sample and the pressure-time curve of the cover rock sample with a pressure drop standard function to obtain a target reservoir section pressure drop function and a cover pressure drop function; and calculating a reservoir physical property similarity coefficient according to the pressure drop function of the target reservoir section, calculating a cap layer physical property deviation coefficient according to the cap layer pressure drop function, taking an arithmetic square root of a product of the reservoir physical property similarity coefficient and the cap layer physical property deviation coefficient as an oil and gas reservoir index, and evaluating the reservoir capacity according to the oil and gas reservoir index. The method has popularization and application values.

Disclosed in the present application are a method for determining the fault sealing capacity of CO2 geological storage, and a related apparatus. The method specifically comprises: determining whether the lithology of a caprock corresponding to a reservoir consisting of CO2 satisfies preset conditions, the preset conditions comprising that the lithology is shale, and the proportion of clay minerals satisfies a preset range; when the lithology of the caprock does not satisfy the preset conditions, calculating a displacement pressure difference between the reservoir and a fault formed between the caprock and the reservoir; and when the displacement pressure difference is not greater than zero, determining a caprock thickness, a reservoir thickness and a fault displacement on the basis of a fault profile diagram; and, on the basis of a numerical value sorting relationship of the caprock thickness, the reservoir thickness and the fault displacement, determining the fault sealing capacity of CO2 geological storage, the fault sealing capacity comprising: a fault being completely sealed, a fault being partially sealed and a fault being unsealed. Therefore, the present application finally determines the fault sealing capacity of the CO2 geological storage.

The invention discloses a test method for overlying strata joint fault instability induced by supercritical CO2 injection, and aims to solve the technical problems that the overlying strata instability process caused by supercritical CO2 injection cannot be effectively simulated under true triaxial stress at present, and CO2 geological storage and development of oil and gas reservoirs are severely hindered. A true triaxial device is used for applying three-way unequal stress, supercritical CO2 is injected by a high-precision high-pressure pump according to a constant rate or flow until the rock is damaged, and the unstability mechanism of the joint fault of the cover layer under different conditions is systematically explored. According to the test method for inducing the unstability of the joint fault of the cover layer by the supercritical CO2 injection, the evolution law of the joint fault of the cover layer by the CO2 injection can be intuitively and accurately observed, the unstability mechanism of the cover layer under a real reservoir condition is comprehensively simulated, scientific and reliable theoretical support and technical guidance are provided for related engineering practice, and the test method has important application value.

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 method for evaluating the closure of a cover layer of an underground gas storage, and belongs to the field of oil-gas exploration. According to the technical scheme, the method comprises the following steps: evaluating the closure of the cover layer of the underground gas storage in three aspects of macroscopic, microscopic and mechanical aspects, and selecting seven key parameters closely related to the closure of the cover layer, wherein the seven key parameters comprise lithology, direct cover layer thickness, permeability, breakthrough pressure, dynamic breakthrough pressure, specific surface area and plasticity coefficient. The method is applied to the aspect of underground gas storage overburden closure evaluation, solves the problem that an existing underground gas storage overburden closure evaluation method cannot accurately evaluate the dynamic closure performance of the overburden in the operation process of the gas storage, and can quantitatively evaluate the static and dynamic closure performance of the overburden from the macroscopic, microscopic and mechanical dimensions; and a scientific basis is provided for site selection and operation of the gas storage.

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 invention belongs to the technical field of microbial remediation, and particularly relates to bacillus megatherium 1-9-1, a microbial agent and application of the bacillus megatherium 1-9-1 and the microbial agent. The bacillus megaterium 1-9-1 is preserved in the China General Microbiological Culture Collection Center on December 21, 2023, and the preservation number of the bacillus megaterium 1-9-1 is CGMCC (China General Microbiological Culture Collection Center) No.29373. According to the application of the bacillus megatherium 1-9-1 in the aspects of repairing the overburden cracks and preventing the gas layer from escaping, the bacillus megatherium 1-9-1 is attached to the surface of the rock, carbonate precipitates are mineralized and deposited around the rock pores and the cracks for repairing, and meanwhile CO2 is absorbed and sealed. After the microbial agent provided by the invention is injected into a cover layer, the metabolite of the microbial agent can block pores and tiny cracks in the cover layer, so that the purposes of better carbon sequestration effect and oil and gas reservoir protection are achieved.

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.

The invention discloses a method and a device for measuring the breakthrough pressure of a low-permeability cap based on absorption spectrum sensing. The measuring device comprises a confining pressure injection module, a data monitoring module, a return pressure setting module, an absorption spectrum sensing module, a rock core holder module and a pore pressure injection module. According to the invention, the breakthrough pressure of the low-permeability cap layer can be tested, the test work can be reliably and efficiently completed, and a pressure signal and an absorption spectrum signal are comprehensively utilized; the absorption spectrum is innovatively applied to the breakthrough pressure test, the rock sample breakthrough moment can be accurately and effectively judged, the sensitivity limitation and delay of pressure monitoring in the low-permeability cover layer test are avoided, and a good detection and tracking system is provided for breakthrough pressure calculation, breakthrough position and form change of displacement fluid; meanwhile, according to the gas monitoring function, the process and efficiency of gas breaking through the rock core can be monitored in real time to a certain extent.

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 invention discloses a qualitative and quantitative identification method for a deep carbonate cap rock, and the method comprises the steps: taking a rock core of a coring section, and determining a cap rock development section and a non-cap rock development section of the rock core; calibrating the core after determining the cap layer development section and the non-cap layer development section and the corresponding imaging logging image, and establishing a relationship between the core and the imaging logging image; establishing a qualitative recognition chart based on mutual calibration of imaging logging and conventional logging; constructing a quantitative identification standard of the deep carbonate cap strata by performing conventional logging multi-parameter intersection analysis; and mutually calibrating the logging data and the seismic data, and determining a spatial distribution map.

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.