737 results about "Core sample" patented technology

The invention discloses a wharf armor block quality detection method, and belongs to the technical field of concrete structure detection.The method comprises the steps that a surface model is constructed through a movable three-dimensional laser scanning device, and a high-risk defect area is recognized; performing encryption scanning and impact echo detection in the high-risk area by adopting a frequency-adjustable dual-mode flaw detection device to generate a three-dimensional defect distribution diagram; a core sample is drilled in the defect area for compressive strength testing, and the material performance is analyzed in combination with a non-contact infrared spectrum; and establishing a dynamic evaluation model, calculating a safety coefficient by integrating surface defects, internal defects and material discreteness data, and generating a three-dimensional visual report. The problems that a traditional detection method is low in efficiency, insufficient in internal defect positioning precision, one-sided in material performance evaluation and the like are solved, full-dimensional detection from the surface to the interior and from the macroscopic level to the microscopic level is achieved through a multi-source data fusion and closed-loop feedback mechanism, and the reliability of structural safety evaluation and the scientificity of maintenance decision are remarkably improved.

A method of estimating an amount of a sequestered carbon-based constituent in a volume of soil that includes taking a core soil sample of a sample volume of soil proximate at and below a root system associated with carbon soil accumulation from a biomass. The core sample is taken at a depth extending from an earthen surface, the depth having a depth range. The core sample is tested to provide a data set.

The invention relates to the technical field of crustal stress measurement, in particular to a rock core three-dimensional crustal stress measurement system and method based on multi-source data. The method comprises the following steps: acquiring well wall damage information, and identifying a damage type in the well wall damage information; multiple sections of core samples are selected based on the well wall damage information, and overburden pressure parameters are determined based on the multiple sections of core samples; a rock mechanics experiment is conducted on the rock core sample, rock mechanics parameters are generated, and the rock mechanics parameters comprise the Poisson's ratio, the Young modulus, the uniaxial compressive strength value and the tensile strength value. According to the method, the difference value of the maximum stress and the minimum stress is combined with the multi-source coupling constraint principal stress interval, the intersection points are identified through the topological visualization graph, the numerical range of the maximum principal stress and the minimum principal stress can be accurately determined, and then the information of the three-dimensional crustal stress is obtained.

The invention relates to an integrated experimental system and method for simulating sand production-sand prevention of an argillaceous silt hydrate reservoir, and the system comprises a reservoir sand production / mechanical property evaluation simulation device which comprises a heat exchange chamber and a high-pressure reaction kettle arranged in the heat exchange chamber, and the high-pressure reaction kettle is internally provided with a core holder; the gas displacement and control device is connected with the reservoir sand production / mechanical property evaluation simulation device; the confining pressure loading device is connected with the high-permeability confining pressure layer in the reservoir sand production / mechanical property evaluation simulation device and is used for simulating the confining pressure environment outside the reservoir core sample; the liquid displacement and control device is connected with the high-pressure reaction kettle and is used for providing liquid displacement conditions for the reservoir core sample; the gas-liquid-solid separation device is connected with the high-pressure reaction kettle and is used for separating a gas-liquid-solid mixture; the visual sand prevention simulation device for the screen pipe unit comprises a visual acrylic pipe, and the data acquisition device is used for acquiring and processing data of the sand prevention experiment of the visual acrylic pipe.

The invention discloses a shale hydrocarbon expulsion efficiency evaluation method, device, equipment and medium, and relates to the technical field of shale gas exploration and developing.The shale hydrocarbon expulsion efficiency evaluation method includes the steps that hydrocarbon generation quantity charts of shale under different total organic carbon TOC grades are constructed; testing the water saturation of the core sample of the shale to obtain the water saturation rate of the core sample; carrying out oil washing treatment on the rock core sample, and carrying out porosity test to obtain rock porosity and rock apparent density; obtaining a crude oil sample of a production layer where the core sample is located, and performing a crude oil physical property experiment to obtain crude oil density; when key parameters such as water saturation rate, rock porosity, rock apparent density, crude oil density and shale hydrocarbon generation quantity charts under different total organic carbon TOC grades of a core sample and key parameters of hydrocarbon release and migration in a hydrocarbon expulsion process are measured, a dynamic measurement process is adopted, and the dynamic measurement process can realize dynamic simulation of a hydrocarbon migration path; and finally, accurate evaluation of the shale hydrocarbon expulsion efficiency is realized.

The invention provides a method and device for predicting the pile-forming strength of a high-pressure jet grouting pile, and relates to the technical field of pile-forming strength prediction.The method comprises the steps that construction parameters are collected in real time through a multi-source sensor, a construction parameter matrix is constructed, and the soil layer boundary depth and the dielectric constant are obtained through geological radar scanning so as to distribute static weight factors; and calculating an intensity correction coefficient based on geological parameters of the core sample, finally establishing an intensity prediction model fusing the dynamic weight, the slurry solidification time, the temperature influence factor and the geological correction coefficient, and setting a three-level early warning mechanism. The core innovation of the scheme is that construction parameters and geological characteristics are dynamically coupled, the model precision is remarkably improved through double calibration of geological radar and core data, and the problem that a traditional method is insufficient in adaptability to soil layer difference is solved through introduction of a geological correction coefficient; and the real-time closed-loop optimization of the construction process is realized through the multi-sensor time synchronization application.

The invention relates to the technical field of carbon dioxide sequestration and shale gas development, and particularly discloses a shale micro-nano pore multiphase multicomponent competitive adsorption data determination method and device, and the method comprises the steps: obtaining a shale core sample of a target area, and determining the type and relative content change characteristics of surface functional groups of the shale core sample; key structures and force field parameters of shale clay minerals in a target block are collected, and a shale clay mineral molecular model is established; establishing a plurality of fluid molecular models; establishing slit models, and establishing a multiphase fluid system model between the slit models to obtain a stable configuration; applying an external electric field to the stable configuration, and performing molecular dynamics calculation to obtain molecular trajectory coordinates and dynamics information of the multi-phase multi-component fluid; and calculating competitive adsorption data of the shale micro-nano pore multi-phase multi-component fluid under the action of the electric field. According to the scheme, the occurrence state and the competitive adsorption behavior of the shale micro-nano pore multi-phase multi-component fluid under the action of the electric field can be disclosed from the molecular scale.

Device (10) for guiding a user to mark a core sample (12) carried by a core tube (14), the device (10) including: a housing (20) mountable relative to the core sample (12) or the core tube (14) and having a marking guide (22) configured to be arranged adjacent the core sample (12) to guide marking; a communications module (26) operable to communicate with the downhole tool (16) to receive data; a user interface (28) operable to convey perceptible feedback to the user; and a processor (30) and associated memory (32). The processor (30) is configured to store data in the memory (32) and determine a marking position based on the data, and operate the user interface (28) to direct the user to cause relative rotation of the marking guide (22) and the core sample (12) so that the marking guide (22) is aligned with the marking position, allowing the user to use the marking guide (22) to mark the core sample (12) at the marking position.

The invention discloses a tunnel stratum recognition method based on shield tunneling machine tunneling parameter machine learning, and relates to the technical field of monitoring analysis, and the method comprises the steps: data collection: constructing a project data set, collecting rock core samples for drilling and coring from the project data set, and determining a learning sample set based on the rock core samples; data feature mining, which is used for obtaining tunneling parameters corresponding to various types of stratums from the learning sample set, mining a statistical feature set responding to stratum changes based on the tunneling parameters corresponding to various types of stratums, and forming a first feature parameter matrix; data feature screening, which is used for carrying out sensitivity analysis on the first feature parameter matrix so as to screen out a second feature parameter matrix; the model construction is used for constructing a stratum recognition model by adopting a K nearest neighbor algorithm based on the learning sample set and the second characteristic parameter matrix; and stratum identification, which is used for identifying the target stratum according to the stratum identification model. The method has the effect of improving the stratum recognition efficiency.

Systems and methods include obtaining well log data and core sample data of a subsurface formation; generating, based on the well log data and the core sample data, an unconfined compressive strength log for the subsurface formation; using an unsupervised machine learning model to form rock type clusters based on the unconfined compressive strength log and the well log data; forming a training dataset including the well log data, the training dataset labeled based on the rock type clusters; training a supervised machine learning model using the training dataset. While drilling a well in the subsurface formation, logging-while-drilling data is obtained from drilling equipment used to drill the well; and rock types in the subsurface formation are determined using the supervised machine learning model and the logging-while-drilling data.

The embodiment of the invention relates to the field of exploration or detection by applying nuclear radiation, in particular to a method for determining a uranium metallogenic area of a to-be-surveyed area, which comprises the following steps of: determining natural gamma logging data and energy spectrum logging uranium content data of the to-be-surveyed area; determining the positions of a plurality of drill holes of the to-be-surveyed area; obtaining a rock core sample of one of the determined drill holes; determining uranium contents at different depths according to the rock core sample; determining the relationship between the uranium content and the energy spectrum logging uranium content data of the drill hole and the relationship between the energy spectrum logging uranium content data and the natural gamma logging data so as to determine the relationship between the uranium content and the natural gamma logging data; and determining a natural gamma logging threshold value of the uranium metallogenic area so as to determine the uranium metallogenic area of the area to be surveyed. According to the method provided by the embodiment of the invention, the natural gamma logging threshold value of the uranium metallogenic area can be accurately determined, so that the uranium metallogenic area of the area to be surveyed can be accurately determined, and the exploration cost is greatly reduced.

The invention relates to a method, a device and equipment for analyzing in-situ formation fracture porosity of mixed rock. Comprising the steps of obtaining original data of a plurality of layers in a target block; taking out a first rock core sample from each layer of the target block, and performing experimental analysis on the first rock core sample of each layer to determine a target layer; taking out a second core sample from the target horizon, and performing a triaxial compression test on the second core sample to obtain a stress index; according to the original data and the stress index, the stratum fracture porosity of the target layer is calculated, the stratum fracture porosity is used for guiding workers to evaluate the real underground in-situ fracture porosity of the reservoir, and therefore an oil and gas reservoir exploitation plan of the target layer is made. The stratum fracture porosity calculated by the method represents the fracture porosity of the target horizon in the target block and represents in-situ characteristics in the stratum, so that the accuracy of reservoir evaluation is improved. A worker can formulate an oil and gas reservoir exploitation plan according to the formation fracture porosity, and the oil and gas reservoir yield is improved.

The invention provides a pile foundation core drilling detection system and method, and belongs to the technical field of core drilling detection. The pile foundation core drilling detection system comprises a core sample storage part, a rotating assembly and a detection assembly; a containing hole is formed in the core sample storage part, a collecting groove extending in the vertical direction is formed in the core sample storage part, and the collecting groove is communicated with the containing hole; the rotating assembly comprises a sub-rotating disc arranged at the bottom of the containing hole and a first driving piece located below the sub-rotating disc. Drill cores are supported at the top ends of the sub-turntables. The bottom end of the sub-turntable extends downwards and is used for being in power connection with a first driving part; the detection assembly comprises a first collector and a controller; in the radial direction of the core sample storage piece, the containing hole corresponding to the to-be-detected drill core, the collecting groove and the information collecting end of the first collector sequentially correspond to one another; the first collector is used for collecting surface information of the drill core through the collecting groove; the detection method is implemented by adopting the pile foundation core drilling detection system. According to the pile foundation core drilling detection system and method, the authenticity and accuracy of core sample detection can be effectively improved.

The invention discloses a rock core identification method and system based on regional geological data, and the method comprises the steps: S1, collecting a rock core sample image, and constructing a rock core image data set; s2, dividing the core image data set into a training set and a test set, and training and testing the constructed classification model based on artificial intelligence; and S3, extracting formation lithology information in the regional geological map, and adjusting and optimizing the trained classification model by using the extracted formation lithology information. When the rock core recognition model is constructed, the regional geological data is introduced to optimize the model, the initial weight assignment of the model is optimized by introducing the regional geological data, the training efficiency, the accuracy and the generalization ability of the model are improved, and the model can be applied to different geological conditions and different regions.

According to the fine fracturing geological modeling method based on the scratch test provided by the embodiment of the invention, the scratch test data representing the mechanical characteristics of a rock core sample material are accurately obtained by carrying out the scratch test on the rock core sample, the mechanical data are calculated and generated according to the scratch test data, and the wavelet transform is carried out on the mechanical data to obtain the fine fracturing geological modeling result. Compared with the prior art, the method has the advantages that the mechanical parameters of the reservoir rock are accurately obtained through scratch testing, the mechanical characteristics of the rock are represented, the mechanical characteristic model is optimized, and design data with higher accuracy is provided for a geological model.

The invention provides a two-dimensional lithology intelligent identification method for a collected rock core. The method comprises the following steps: step 1, collecting and analyzing rock core and geological information of a research area; 2, performing optical scanning on the rock core to generate a rock core optical image; step 3, performing preprocessing and manual marking on the rock core optical image; 4, carrying out a machine learning-based label sample fine processing technology by utilizing the obtained optical image data and the rock core label, and generating an intelligent training label sample set; and 5, establishing a U-Net + +-based two-dimensional rock core image recognition model, and forming an artificial intelligence-based rock core scanning and digital logging technology. According to the invention, a digital target of a physical rock core library in a geological reference center and intelligent identification of unidentified rock cores can be realized.

Systems and methods for modeling gas desorption in a subterranean reservoir include measuring a gas sorption parameter using a crushed core sample from the subterranean reservoir; computing a gas storage capacity of the subterranean reservoir at an initial reservoir pressure based on the gas sorption parameter; generating a three-dimensional (3D) distribution of total organic carbon (TOC) in the subterranean reservoir; estimating a 3D distribution of original adsorbed gas in place of the subterranean reservoir by correlating the gas storage capacity with the 3D distribution of TOC; and predicting the amount of gas desorbed from the subterranean reservoir as the reservoir is depleted.

The invention relates to a method for detecting the strength of ultra-high performance concrete through a core drilling method with the diameter of 52 mm. The method comprises the following steps that S1, steel bar distribution is detected on a to-be-detected ultra-high performance concrete member through a steel bar detector, and a steel bar distribution grid is drawn; s2, core samples with the diameter of 52 mm are drilled in the grids; s3, after processing the core sample, carrying out a compressive strength test to obtain a compressive strength value of the core sample; and S4, presuming the structural concrete strength by utilizing a correction coefficient formula according to the compressive strength value of the ultra-high performance concrete core sample. According to the method, the optimal core sample size of UHPC sampling is obtained through a contrast test, a correction coefficient formula suitable for the UHPC optimal core sample is obtained according to test data, the obtained optimal core sample size meets the standard requirements, damage to the UHPC component is minimum, and the strength of the UHPC component can be obtained.

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

The invention belongs to the field of petroleum and natural gas engineering, particularly relates to a method and a system for converting XRF logging elements and mineral content, and aims to solve the problems of long time for judging the mineral content by XRD and low cost performance. The method comprises the steps that XRF logging element and XRD mineral content detection is conducted on a coring sample according to the well depth, and XRF logging element detection data and XRD mineral content detection data are obtained; classifying minerals corresponding to the coring samples to obtain mineral types, extracting elements of the mineral types, and screening the elements to obtain characteristic elements; performing linear regression analysis on the XRF logging element detection data corresponding to the characteristic elements and the XRD mineral content detection data corresponding to the characteristic elements to obtain mineral content models of different mineral types; and substituting XRF logging element data of any well depth into the model to obtain the mineral type content of the well depth. According to the method, the mineral type content can be judged according to the XRF logging elements.

The invention discloses a method for accurately evaluating the erosion damage depth of hydraulic concrete, which relates to the technical field of concrete damage detection, and comprises the following steps: carrying out three-dimensional scanning on a surface damage area of an abraded hydraulic concrete test piece, and selecting random points to carry out drilling and coring operation so as to obtain a concrete core sample. According to the method, multiple detection means including three-dimensional scanning, computed tomography and microhardness testing are combined, the punching wear damage depth of the hydraulic concrete is accurately measured, and the damage form and depth information of the concrete surface is rapidly obtained through three-dimensional scanning; computed tomography deeply detects microcracks and pore distribution in concrete, microhardness test further accurately positions the damage depth, the limitation of a traditional detection method on detection precision is effectively overcome, more accurate damage depth data can be provided, and a reliable basis is provided for maintenance and repair of a hydraulic concrete structure.

The present invention relates to a core drilling assembly, comprising an outer barrel assembly that includes a drill bit at one end and a coupling for connection to the drill rods at the other end thereof, the outer barrel assembly carrying an inner tube assembly that includes at least a core catcher, an inner tube and a head assembly, the core catcher being configured to grip and rotationally fix at least a section of the core sample relative to the core catcher thus also the inner tube and head assembly thereof, also including, - a measuring device being connected to the forward end of the head assembly, being mechanically and electromagnetically shielded from the outer environment, - the measuring device comprising at least a sensor and a data storage configured to measure and store the rotational orientation of the head assembly.

The invention discloses a method for segmenting different strata series of stratified shale and identifying oiliness, and belongs to the field of oil-gas exploration. The invention discloses a strata division method based on XRF (X-Ray Fluorescence) mineral scanning and single polarization-fluorescence-laser confocal optical lens combined observation, which realizes accurate identification and segmentation of micron-sized strata boundaries of a layered rock core sample from different scales, and performs group component extraction on segmented independent strata. And carrying out chromatography-mass spectrometry analysis and FT-ICR MS analysis on the extracted saturated, aromatic, non-aromatic, leached and other family components. The TSF spectrum, light and heavy components, biomarker compounds, non-hydrocarbon compounds and other data obtained through the experiments are comprehensively analyzed, layering scale oiliness difference quantification and oil source comparison are achieved, and the shale oil micro-migration phenomenon is determined. The influence of the heterogeneity of the layered rock core sample on a result obtained by a traditional analysis method is overcome. According to the technology, direct evidences are provided for accurate prediction of shale oil desserts, exploration risks are reduced, and economic benefits are improved.

The invention relates to the technical field of oil and gas geophysical exploration, in particular to a high-resolution seismic inversion recognition method for a thin and small reservoir of an oil reservoir. The method comprises the following steps: performing digital core model construction on a thin and small reservoir core sample to obtain a three-dimensional digital core model; carrying out multi-mineral component quantitative analysis on the thin and small reservoir core sample to obtain mineral components and distribution data; performing fracture geometric analysis on the three-dimensional digital core model to obtain fracture geometric analysis data; constructing a microscopic rock physical model according to the fracture geometric analysis data and the mineral composition and distribution data, and calculating physical model parameters to obtain microscopic rock physical parameters; and calculating matrix pore elastic parameters according to the microscopic rock physical parameters to obtain pore-containing dry rock elastic parameters. According to the method, the problems that a traditional method is low in resolution and influences of reservoir fluid and fractures are ignored are effectively solved, and high-precision recognition and fine description of the thin and small reservoir are achieved.

The invention belongs to the field of single-well gas injection, and discloses a low-permeability tight oil reservoir single-well CO2 gas injection and displacement speed determination method and a related device. The method comprises the following steps: constructing a carbon dioxide gas flooding and injection velocity model containing matrix overburden pressure permeability and starting pressure gradient; the method comprises the following steps: testing the permeability of a reservoir core sample of a tight sandstone reservoir under different effective stresses to obtain a first relation curve, and carrying out regression analysis to obtain a first coefficient corresponding to the matrix overburden pressure permeability; respectively carrying out starting pressure gradient testing on the core samples with different matrix overburden pressure permeability to obtain a second relation curve, and carrying out regression analysis to obtain a second coefficient corresponding to the starting pressure gradient; and the collected basic data, the first coefficient and the second coefficient are input into the carbon dioxide flooding gas injection speed model for calculation, and the gas injection speed of the single well is obtained. According to the method, the carbon dioxide flooding and gas injection speed can be better optimized, and therefore the exploitation efficiency of an oil field is improved.

The invention relates to a shale full pore size distribution and connectivity quantitative characterization method. The method comprises the following steps: respectively determining a two-dimensional nuclear magnetic resonance T1-T2 spectrum and a nuclear magnetic resonance T2 spectrum of a dry sample core and a saturated oil core, carrying out a high-pressure mercury injection test on a parallel sample of the core, completing benchmarking of T2 and pore throat radius, and determining core communication aperture distribution; (2) splitting the rock core into sheets along the lamella, determining a two-dimensional nuclear magnetic resonance T1-T2 spectrum of the sheet-shaped dry sample rock core, comparing the two-dimensional nuclear magnetic resonance T1-T2 spectrum with the T1-T2 spectrum of the dry sample rock core, and calculating the distribution of the disconnected seams of the rock core; (3) grinding the rock core into 200-mesh particles, measuring the two-dimensional nuclear magnetic resonance T1-T2 spectrum of the granular dry sample rock core, comparing the two-dimensional nuclear magnetic resonance T1-T2 spectrum with the T1-T2 spectrum of the sheet-shaped dry sample rock core, and calculating the distribution of disconnected holes of the rock core; and (4) calculating shale full pore size distribution and connectivity. According to the method, nuclear magnetic resonance testing is carried out on shale in different states and forms, and quantitative characterization of shale full pore size distribution and connectivity of different storage spaces is achieved.

A rapid assembly and automatic sampling drilling tool for frozen soil layer exploration includes a fixed flow divider, a flow guide pipe, a coring pipe and a drill bit. The fixed flow divider is connected to the drill bit through the flow guide pipe and the coring pipe mounted between the fixed flow divider and the drill bit. Two ends of the flow guide pipe communicate with the fixed flow divider and a main flow channel in the drill bit respectively. Hot water in the fixed flow divider can be conveyed into the drill bit through the flow guide pipe and sprayed from a nozzle arranged on the drill bit for drilling and coring operations. An inlet of the coring pipe communicates with a coring channel in an inner cavity in the drill bit, and a core sample drilled by the drill bit is taken out through the coring pipe.

The invention discloses a method, a device and equipment for determining mobility of shale oil. The method comprises the following steps: acquiring core parameter data and nuclear magnetic resonance data of a plurality of core samples of a target reservoir in an imbibition experiment process; determining the maximum imbibition displacement oil porosity of the plurality of core samples based on the nuclear magnetic resonance data; based on the core parameter data of the plurality of core samples and the maximum imbibition displacement oil porosity of the plurality of core samples, determining key parameters influencing shale oil mobility of the target reservoir in the core parameters of the core samples; and obtaining the value of the determined key parameter from the core parameter data, and determining the relationship between the shale oil mobility and the key parameter based on the value of the key parameter and the maximum imbibition displacement oil porosity of the plurality of core samples, so as to determine the shale oil mobility of the target reservoir based on the relationship. According to the method, the shale oil mobility is more accurate and reliable, and the practicability is higher.

The utility model discloses a geological drilling coring device which comprises a frame body, a placing table is installed on the upper portion of the frame body in a sliding mode, a motor is connected to the upper portion of the placing table through bolts, the motor is connected with a transmission shaft through a belt, a coring barrel is fixedly connected to the bottom of the transmission shaft, and a drill bit is fixedly connected to the bottom of the coring barrel. A cutting-off structure is arranged in the coring barrel and comprises a cavity and a first gear, a sliding block is slidably installed in the cavity, a rack is fixedly installed on the upper portion of the sliding block, a second gear is rotatably installed in the cavity, the second gear is connected with the rack in a meshed mode, and a double-face gear ring is rotatably installed at the upper position in the cavity. The double-face gear ring is connected with the second gear in a meshed mode, the double-face gear ring is connected with the first gear in a meshed mode, and a rotating shaft is fixedly installed at the top of the first gear. According to the geological drilling coring device disclosed by the utility model, a required core sample can be completely stored in the device.

The invention discloses a shallow shale gas self-sealing reservoir formation identification method, which comprises the following steps: firstly, carrying out dual-energy CT scanning on a shale full-diameter core sample to obtain DEI values, and the difference of the DEI values embodies different lithologic (physical property) longitudinal change rules, i.e., different shale lithologic grain interlayer interlayers, different shale lithologic grain interlayer interlayers, different shale lithologic grain interlayer interlayers, different shale lithologic grain interlayer interlayers, different shale lithologic grain interlayer interlayers, and different shale lithologic grain interlayer interlayers; the development of the top and bottom plates of the high-quality shale reservoir enables the shale gas to have a self-sealing reservoir forming characteristic; then simulating the adsorbability of the shale gas through laboratory thermal cracking to obtain a shale gas adsorbability rule, and identifying whether the shale gas has a self-sealing reservoir forming characteristic or not. And finally, measuring the distribution rule of the microscopic porosity and the pore diameter through a scanning electron microscope, judging whether the shale layer is a non-or ultra-low permeability layer under the formation temperature and pressure condition or not, and identifying whether the shale gas has the self-sealing reservoir forming characteristic or not. According to the method, the self-sealing reservoir forming of the shale gas is identified in multiple aspects, and the method provides effective technical support for evaluating the favorable layer section of the shale and is of great significance in improving the exploration and development effect of the shale gas.