69 results about "Rock density" patented technology

The invention provides a method for predicting the transversal wave velocity of a carbonatite rock reservoir and relates to the technical field of geophysical exploration. The method comprises the following steps: determining the mineral component, the reservoir porosity as well as the fluid saturation of the reservoir; dividing the reservoir porosity into a rigid porosity, a fracture porosity and a clay porosity; obtaining the parameters of each mineral in the reservoir; calculating the bulk modulus Km and the shear modulus mum of a rock matrix through a Voigt-Reuss-Hill average model; calculating rhom; generating kfl and rhofl; generating the equivalent density rhodry of a rock dry skeleton; sequentially adding the porosities into the rock matrix through a DEM model, and calculating Kdry and mudry; carrying out fluid replacement on the rock dry skeleton through a low-frequency Gassmann equation so as to generate the density rho of a saturated fluid rock; calculating Ksat and musat; calculating the longitudinal wave speed (as shown in the description) and the transversal wave speed (as shown in the description) of the saturated fluid rock, inverting a virtual fracture porosity phi'f by a simulated annealing method according to a first relative error (as shown in the description) or a second relative error of rho and rhoo; replacing phif with phi'f, returning and calculating to generate the transversal wave speed V1 of the carbonatite rock reservoir.

The invention discloses a shale classification method. The method includes the first step of determining the types of macroscopic structures of shales by observing shale cores, the second step of determining organic matter types and total content of organic carbon through kerogen and organic carbon analysis and obtaining the volume fraction of organic matter components through the total content of organic carbon, a conversion coefficient, the organic matter density and the rock density, the third step of determining mineral composition of the shales and obtaining the volume fraction of calcareous mineral components, the volume fraction of felsic mineral components and the volume fraction of clay mineral components through thin section authentication and total rock mineral analysis, the fourth step of classifying the shales according to the four-component three-end-member principle, and the last step of classifying the shales and conducting reasonable simplification through a core macroscopic structure and rock type combined method. The shale classification method is applicable to laboratory studies and outside work, is a method with reasonable logic and high operability for classification of the shales, solves the problems that the shale classification methods are varied and the organic matter components are ignored, and can be used for studying formation causes of the shales conveniently and guiding field logging and fracturing transformation.

The invention discloses a total shale gas reservoir organic porosity degree computing method and device. The method includes the steps that the organic porosity K of a shale gas reservoir is obtained; the conversion coefficient C for the organic carbon in the shale gas reservoir to be converted into organic matter, the organic carbon content TOC of the shale gas reservoir, the rock density phi r of the shale gas reservoir and the organic matter density phi o of the shale gas reservoir are obtained; the specific value obtained by dividing the phi r by the phi o, and then the product of the C and the TOC is multiplied by the specific value to obtain the total organic matter volume rate Nb; the product of the Nb and the K is worked out to obtain the total organic porosity degree Rho. According to the method, through the relation deduction of the mass, volume, density and organic matter content, the method aims to solve the problems that in the prior art, the total organic porosity degree of the shale gas reservoir cannot be obtained through detection, and no standard computing formula exists, and the method and device can have significant application value on the aspects of the total shale gas reservoir organic porosity degree computing and shale gas reserves evaluation.

The invention relates to a horizontal well crack recognition method. The horizontal well crack recognition method comprises the following steps: detecting a horizontal section of a horizontal well to obtain a well logging curve which is sensitive to a crack and a rock density curve, and further reconstructing to obtain a crack fractal index curve, a crack feature index curve and a stratum brittleness index curve; obtaining a crack index curve according to the various curves obtained by reconstruction; and recognizing development degree of the crack of the horizontal well in the horizontal direction according to the crack index curve, wherein the development degree of the crack is increased along with increasing of crack indexes. According to the method provided by the invention, response strength of the crack is amplified by well logging data, non-crack influences are eliminated, crack information is extracted comprehensively from the well logging data, and cracks of the stratum surrounding the horizontal well are recognized accurately.

The invention provides a nonlinear earthquake pre-stack elastic parameter inverting method based on regularization. The method comprises the following steps of: obtaining a multi-angle ray elasticity impedance well curve REIi according to the known logging information and ray elasticity impedance; introducing the known position, the fault data and the multi-angle ray elasticity impedance well curve REIi to establish ray elasticity impedance models of the whole work area from different angles; calculating part superposition data bodies of different angles of incidence by using the pre-stack offset gather; inverting by virtue of a sparse pulse inverting algorithm to obtain a ray elasticity impedance data body corresponding to the angle of incidence; introducing the ray elasticity impedance data body corresponding to the angle of incidence into the nonlinear Landweber-Fridman iterative algorithm to obtain the longitudinal-transverse wave speed and rock density of the whole work area so as to calculate other lithology parameters. By utilizing the method, inversion calculation is carried out by using multi-angle REIi data and the nonlinear Landweber-Fridman iterative algorithm, so that accurate lithology parameters can be obtained.

The invention provides a method and a system for predicting formation pressure of an exploratory well. The method comprises the following steps: calculating a rock density curve which is not tested bya shallow well logging, splicing the density curve obtained by the well logging and obtaining a density curve rho (d) from a surface to a deep reservoir; Calculating an overlying formation pressure SV (d) and a hydrostatic pressure Phy (d); Calculating formation pressure of shallow clastic rock formation; Calculating formation pressure of gas-bearing shale reservoir; Calculating formation pressure of carbonate reservoir; Based on the results calculated in the above steps, a final pressure predicted logging profile is obtained. By using different pressure prediction models for different lithology, the prediction accuracy of well logging formation pressure can be effectively improved.

The embodiment of the invention discloses a method and device for determining the fracturing indexes of a reservoir stratum. Logging data of the target reservoir stratum at a target well position areprovided; the target reservoir stratum comprises a plurality of sampling points at the target well position, and the logging data comprise logging parameter information at the sampling point positions. The method comprises the following steps that based on the content of rock mineral components in the logging parameter information, the brittleness indexes at the sampling point positions are determined; based on the rock density and the interval transit time in the logging parameter information, the fracturing toughness indexes at the sampling point positions are determined; based on the porosity in the logging parameter information, the rock uniaxial compressive strength at the sampling point positions are determined; and based on the brittleness indexes, the fracturing toughness indexes and the rock uniaxial compressive strength, the fracturing indexes at the sampling point positions are determined. According to the technical scheme provided by the embodiment of the invention, the accuracy of the determined fracturing indexes of the reservoir stratum can be improved.

The invention discloses a method for determining a blasting action area of a cylindrical charge in rocks. The method comprises the following steps: according to the characteristic data of the following rocks and explosives before and after the cylindrical charge is exploded in rocks, namely the radius of a blast hole, the compressive strength of the rocks, the tensile strength of the rocks, the density of the rocks, the density of the explosives, the detonation velocity of the explosives, the longitudinal wave velocity and the Poisson's ratio of the rocks, bringing the above characteristic data into the formula I-1, formula I-2, formula I-3, calculating to obtain the blasting action area of the cylindrical charge in rocks, namely the radius of an enlarged cavity, the radius of a crushing area and the radius of a rupture area, which are respectively marked as r1, r2 and r3. According to the method, the enlarged cavity, the crushing area and the rupture area with rock mass destruction characteristics can be obtained through a model of a single column-shaped charge acting area in rocks. The compound structure is shown in the description.

The invention relates to a calculation method of reasonable delay time of single-hole-interval millisecond vibration-absorbing blasting of an electronic detonator. The method comprises the following steps: acquiring tunnel surrounding rock density and longitudinal wave propagation speed cP; measuring plane geometry parameters of each blast hole; calculating the diameter, the blast depth and the charge coefficient of each blast hole; calculating the time for stress wave arriving at the closest free face after a blasting cartridge in each blast hole blasts; calculating the time t2n for a crack,arriving at an excavating face, of each blast hole in the blast hole length direction; calculating the time t3m for a prism object throwing to reach the distance of 10cm from a new free face, whereinthe prism object is encircled by the blasting cartridge in each blast hole after blasting; calculating the total delay time of the electronic detonator in each blat hole; calculating blasting seismicperiod Tn of assisting holes and surrounding holes under different charge mass; setting the delay time of the electronic detonator in each blast hole based on the calculation result; and adjusting thedelay time of each blast hole based on the field blasting test and the monitoring result. With the adoption of the method, good ore crushing effect is ensured; the blasting vibration is greatly absorbed; the social benefit and the economic benefit are high.

The invention discloses a deposition numerical-value simulation method of fine-grain sediments. According to the method, fine-grain sediment settlement rates v of different deposition modes are calculated according to the different deposition modes; denudation amount m<denudation> of the sediments is calculated through a denudation formula, and the deposition settlement rates v and the denudationamount m<denudation> of the sediments are used to calculate and obtain mass m<deposition> of the sediments of the different deposition modes; The mass m<deposition> of the sediments of the different deposition modes is used to carry out summation calculation to obtain total deposition amount m <total> of the sediments; and volume of the sediments is calculated according to a rock density formula,deposition thickness of the sediments is calculated according to a grid area size and thickness formula, the deposition thickness is superimposed onto an initial bed form to obtain changes of the deposition bed form until simulation ends, thus realizing quantitative characterization for a study area, and realizing numerical-value simulation for the fine-grain sediments. According to the method, deposition processes of fine-grain deposition are clarified, various processes of fine-grain deposition are fully considered, and simulation requirements of fine-grain deposition are satisfied.

The invention, which belongs to the field of studying of the diagenetic numerical value simulation technology of the low-permeability-tight reservoirs, provides an analytical method for the evolutionhistory of 3D permeability of a sandstone reservoir. The method comprises the following steps that: well selection and data arrangement are carried out; a rock physics model including six types of lithofacies of coarse sandstone, medium sandstone, fine sandstone, siltstone, chiltern conglomerate and mudstone is established in a low-permeability-tight reservoir, and distribution of the six types oflithofacies at a target segment is evaluated by using combined scales of six kinds of welllogging curves; on the basis of a sandstone particle size, a rock density, and mineral constituents, six lithofacies types approximating geological actual situation are made; a porosity-depth and porosity- permeability mathematical equation based on magnetic resonance imaging and reservoir physical data is implanted and thus a 3D permeability evolution history of the six lithofacies types at the target segment is reproduced under the 3D burial history and thermal history constraints; and an overall 3D permeability evolution history of the target segment is evaluated by combining the percentage compositions of the six lithofacies types. Moreover, the consistency analysis of a practically measured permeability value and a simulated permeability value is carried out.

The invention relates to a rock density measurement and a rock density measurement device, wherein the method includes the following steps: (1) making a rock sample which is cylindrical in structure; (2) weighing the mass of the rock sample; (3) measuring the axial height and the bottom diameter of the rock sample; (4) placing the rock sample in a high pressure chamber; (5) increasing the temperature of the high pressure chamber, applying axial pressures on the bottom surface and the top surface of the rock sample for fixing the rock sample, and applying a radial pressure to a side surface of the rock sample; (6) detecting the axial strain quantity of the rock sample and the radial deformation quantity of the bottom surface of the rock sample; and (7) obtaining the density of the rock sample. The method can be used for measuring the rock density at a high temperature and under a high pressure.

The invention provides a method and a system for acquiring three-dimensional rock mechanical parameters. The method includes the following steps: 1) acquiring transverse wave time difference and longitudinal wave time difference according to known acoustic logging data of a well, determining the relationship between the transverse and the longitudinal wave time differences, and according to the relationship, determining transverse wave velocity and longitudinal wave velocity; 2) according to density logging data and the longitudinal wave velocity, determining a density-wave velocity relationship between the rock density and the longitudinal wave velocity; 3) according to the longitudinal wave velocity, calibrating earthquake velocity field data; 4) calculating the three-dimensional rock mechanical parameters according to the calibrated earthquake velocity field data and the rock density to obtain dynamic three-dimensional rock mechanical parameters; and 5) converting the dynamic three-dimensional rock mechanical parameters into corresponding static values. The method for acquiring the rock mechanical parameters comprehensively considers the logging data and earthquake data and can adapt spatial non-continuity in a three-dimensional geologic body, so that the method has better adaptability.

The embodiment of the invention provides a method and a device for determining gas content of tight reservoirs. The method comprises the following steps: preparing a plunger sample with first specification and a particle sample with second specification from a sample of tight reservoirs; carrying out an adsorption experiment on the particle sample to obtain a reservoir sample gas-adsorption quantity calculation model including temperature, pressure and rock thermal evolution degree parameters; carrying out porosity and rock density determination on the plunger sample to obtain a free gas quantity calculation model including porosity, density, gas saturation, adsorption gas density, stratum correction factor and methane molecule molar mass; and calculating gas content of the tight reservoirby the utilization of the reservoir sample gas-adsorption quantity calculation model and the free gas quantity calculation model. By the technical scheme provided by the embodiment of the invention,gas content of the tight reservoirs can be accurately determined so as to provide data support for accurate evaluation of unconventional natural gas resource quantity.

The invention discloses a drilling fluid density determination method capable of controlling creep shrinkage of boreholes in a frozen earth stratum. The method includes the following steps of drillingrock cores at different depths in the frozen earth stratum, selecting one rock core at a certain depth under a certain temperature to carry out a frozen earth creep experiment, and calculating creepparameters; creating a correlation between the creep parameters and the temperature; conducting a mechanical test of the rock core to obtain elasticity modulus, a Poisson's ratio and rock density; creating a correlation between the creep and the depth of the stratum and a relation between the rock density and the depth of the stratum; creating a correlation between the temperature of the stratum and the depth; according to stress performed on surrounding rock of a well wall, obtaining a balance equation, a geometric equation and boundary conditions and figuring out simultaneous equations to obtain a drilling fluid density equation; determining drilling liquid density for controlling the shrinkage rate of the boreholes in all well sections of the frozen earth stratum under different workingconditions and drawing a drilling fluid density graph. On the basis of creep mechanical behaviors of frozen earth, the drilling fluid density graph for drilling of the frozen earth stratum after viscoelasticity is taken into account is provided, and the method has an extremely significant engineering meaning.

The invention belongs to the technical field of testing mechanical properties of rocks, and discloses a system and a method for testing and controlling the mechanical properties of the rocks under a complicated condition. The system for testing and controlling the mechanical properties of the rocks under the complicated condition comprises a hardness detecting module, a tension detecting module, apressure detecting module, a temperature-humidity detecting module, a main control module, a density measuring module, a rock phase analysis module, a data storage module and a display module. According to the system for testing and controlling the mechanical properties of the rocks under the complicated condition, disclosed by the invention, a rock sample can be constructed into a cylinder of which the volume can be conveniently obtained through the density measuring module, the axial size and the radial size of the rock sample can be changed by respectively applying pressure to the top surface, the bottom surface and the side surface of the rock sample, and the heated and pressurized rock sample still is the cylinder, so that the volume of the heated and pressurized rock sample can be obtained, and measurement of rock density can be convenient; meanwhile, fine laminating of a big, very thick and single shale layer section can be rapidly solved through the rock phase analysis module.

The invention belongs to the technical field of geological prospecting, and discloses a method for obtaining the total porosity of a shale gas reservoir. The method comprises the following steps: obtaining a rock density pmatrix of the shale gas reservoir; obtaining a dry rock bulk modulus Kmatrix of the shale gas reservoir; acquiring a dry rock shear modulus mu of the shale gas reservoir; calculating a transmission speed Vpmatrix of sound waves in particles of the shale gas reservoir according to a formula; calculating the total porosity phi of the shale gas reservoir by adopting a method for calculating the porosity by using the sound waves according to the transmission speed Vpmatrix of the sound waves in the particles of the shale gas reservoir. The method provided by the invention can realize high-precision and high-efficiency porosity measurement.

The invention belongs to the field of nuclear physics research and application, and specifically relates to a gamma-gamma density logging distorted curve correction method. The invention provides a correction method for eliminating gamma-gamma density logging curve distortion produced due to rock radiation in the stage of gamma-gamma density logging data sorting. The method comprises the following steps: S1, selecting a correction depth section; S2, calculating the density value of a rock skeleton; S3, calculating the average correction coefficient value; and S4, calculating the rock density of the correction depth section and drawing a corrected gamma-gamma density curve. The problem that a curve fluctuates drastically in a uranium enrichment section before correction is solved. Accurate acoustic impedance data can be provided for seismic exploration, and the quality of gamma-gamma density logging can be monitored effectively. The correction method is also applicable to a gamma-gamma density logging distorted curve affected by a hole enlarge section and a hole collapse section.

The present invention discloses a method and apparatus for predicting TOC (total organic carbon content) in a shale reservoir. According to the method and apparatus of the invention, a shale reservoir rock physical model is utilized to predict the TOC in the shale reservoir based on a plurality of attribute constraints such as longitudinal wave impedance Ip, transverse wave impedance Is and rock density Rho under a Bayesian framework. The prediction result of the method and apparatus is stable and reliable. The method and apparatus are suitable for processing seismic data with a low signal-to-noise ratio.

The present disclosure relates to a system and program for predicting shearing by fluid pressure, the system and program capable of predicting shearing information such as the minimum pressure Pcm required for hydraulic shearing, the sufficient pressure Pco for hydraulic shearing, and the optimal shearing direction using input information including the vertical stress σv, the maximum horizontal stress and the minimum horizontal stress of a rock to which fluid is to be injected, a joint friction angle φ, a reservoir rock density ρr, an injected fluid density, and a coefficient of the sufficient pressure for hydraulic shearing α.

The invention discloses a method for calculating the rock density based on scattering energy spectrum dual-energy windows and belongs to the technical field of physical properties of rocks. A device for measuring the rock density based on the scattering energy spectrum dual-energy windows is adopted to calculate the rock density, and firstly a scattering gamma-ray spectrum is recorded based on the principle that gamma rays and substance produce Compton scattering; the high-energy window and the low-energy window are selected, a simulation or graduation method is utilized to obtain the function relation of counting of scattering gamma rays of the high-energy window and the low-energy window and density response; the relation of the density measurement value correcting volume and the difference between density measurement values of the high-energy window and the low-energy window is further obtained to offset the interference of lithological characters to measurement results, and accordingly the density of a measured sample is accurately calculated. Compared with an existing radioactive method based substance density measuring technology, the method has the advantages of being accurate, quick and convenient to calculate, being not subjected to the influence of the lithological characters, and the like.

The invention discloses a method and device for determining the moment magnitude of a microseism event, and the method comprises the steps: carrying out the Fourier transform of longitudinal and transverse waves collected by a detector, and determining the main frequency of the microseism event; determining a propagation path and propagation duration of the microseism event according to the time difference data of the longitudinal and transverse waves acquired by the detector; according to the maximum amplitude value of the longitudinal and transverse waves collected by the detector, the mainfrequency of the microseism event and the propagation duration of the microseism event, determining the maximum amplitude value of the longitudinal and transverse waves at the rock fracture position of the microseism event; determining the seismic moment of the microseism event according to the maximum amplitude value of the longitudinal and transverse waves at the rock fracture position of the microseism event, the propagation path of the microseism event, the rock density and the propagation speed of the longitudinal and transverse waves collected by the detector; and determining the momentmagnitude of the microseism event according to the seismic moment of the microseism event. The calculation precision of the moment magnitude of the microseism event can be improved.

The invention discloses an oil and gas saturation prediction method independent of logging information, and the method comprises the steps: carrying out the geological background investigation, and obtaining the prior probability distribution of rock physical parameters; carrying out multiple times of random sampling on each rock physical parameter in all the rock physical parameters with prior probability distribution to obtain a plurality of numerical values, and obtaining rock physical parameter sampling values; presetting an R-H-G rock physical empirical model and a rock density equation; substituting the rock physical parameter sampling value, calculating the corresponding longitudinal wave speed, density and longitudinal wave impedance, and obtaining posterior probability distribution data between the longitudinal wave impedance and the oil gas saturation; and performing fitting optimization by taking the longitudinal wave impedance as an independent variable and the oil gas saturation as a dependent variable to obtain a calculation formula for calculating the oil gas saturation through the longitudinal wave impedance, and predicting the oil-gas saturation according to a prediction formula by taking the calculation formula as the prediction formula. According to the method, the oil gas saturation can be predicted without depending on logging information.

The invention discloses a method for predicting high-quality reservoir in gravity flow channel sand and relates to the field of petroleum geological engineering. The method comprises steps as follows: well logging data of gravity flow channel sand in multiple single wells are obtained, and the porosity, the rock density and the longitudinal wave velocity of corresponding gravity flow channel sand in each single well are obtained; corresponding wave impedance of gravity flow channel sand in each single well is further obtained; a porosity-wave impedance interactive chart is established on the basis, and the high-quality reservoir in the gravity flow channel sand is determined according to the chart; wave impedance inversion is performed on target gravity flow channel sand reservoir, and quantitative distribution of the target gravity flow channel sand reservoir is obtained in combination with information of the high-quality reservoir, determined according to the porosity-wave impedance interactive chart, of the gravity flow channel sand. By means of the predicting method, distribution of high-quality reservoir of the gravity flow channel sand can be quantitatively predicted, the blindness of well drilling is eliminated, and the success rate of well drilling is increased.

The invention discloses a fluid identification method and device, and belongs to the field of oil and gas field exploitation. The method comprises the steps: obtaining target parameters of an area where a target well is located in a reservoir, wherein the target parameters comprise porosity, rock density, formation water mineralization degree, rock chlorate content and a water saturation thresholdvalue; determining a specified parameter value of an area where the target well is located in the reservoir based on the target parameter, the specified parameter value comprising at least one of a rock chlorate content threshold and water saturation; and determining the fluid type of the area where the target well is located in the reservoir based on the specified parameter value and the targetparameter. According to the method and the device, the problem of relatively high complexity of identifying the fluid in the reservoir is solved. The method is used for identifying the fluid type in the reservoir.

The invention relates to the technical field of while-drilling stratum pressure calculation methods, in particular to a method of acquiring the while-drilling stratum pressure by fitting logging parameters based on while-drilling rock and mineral data. The method comprises the steps of calculating the rock density, the shale content, the vertical effective stress, the acoustic wave velocity and the porosity of a while-drilling stratum according to the while-drilling rock and mineral data; and calculating the while-drilling stratum pressure through calculated parameters. According to the methodof acquiring the while-drilling stratum pressure, through combination of the while-drilling rock and mineral analysis data acquired continuously in time and an interpretation method that logging is not limited by undercompaction causes, a stratum pressure calculation method under multiple pressure formation mechanisms is established. Moreover, the correlation of the while-drilling stratum pressure calculated through the method of acquiring the while-drilling stratum pressure and the logging interpretation stratum pressure is very high, evaluation of a site for the stratum pressure is met, thedrilling fluid density can be guided, and the risk early warning of the stratum pressure can be given.

The invention relates to a porosity logging calculation method for a corrosion type reservoir. The porosity logging calculation method comprises the following steps that step 1, according to the characteristics of rock of the corrosion type reservoir, sensitive elements closely related to rock components are optimally selected by adopting correlation analysis of lithology and elements; step 2, data intersection analysis is carried out through porosity (POR) and core density (DEN) of a drilled well, a stratum rock area is divided into a non-corrosion interval, a partial corrosion interval and acorrosion development interval, and the corresponding POR numerical interval ranges are as follows: POR is smaller than 2.2%, POR is larger than 2.2% and smaller than 3.5%, and POR is larger than 3.5%; and step 3, a calculation model for calculating the porosity of the elements is established among the intervals. According to the porosity logging calculation method for the corrosion type reservoir, through intersection of the porosity of the drilled well and the rock density, the stratum rock is divided into the non-corrosion interval, the partial corrosion interval and the corrosion development interval, a porosity calculation model is established by applying XRF element logging data through multiple regression analysis in an interval mode, a calculation result is consistent with the trend of well logging interpretation, and the purpose of obtaining the stratum porosity in the drilling process is achieved.

The invention discloses a method for obtaining fault rock displacement pressure based on rock debris. The method comprises the following steps: (1) performing rock debris depth correction; (2) calculating the surrounding rock displacement pressure according to the correction result of the rock debris depth in the step (1); (3) calculating fault rock displacement pressure, enabling fault rock to be equivalent to a horizontal stratum at a certain depth underground, and recording the thickness of a small layer of a surrounding rock i outside a fault zone as delta Zi; calculating according to a formula III to obtain fault rock displacement pressure; wherein Pdf is equal to 0.00191n(H<fault>*(rho r - rho w)*cos theta / rho<r>* Sigma(Vshi*Delta Zi / D)*100%)-0.0052 (formula III), and in the formula III, Pdf is fault rock beat replacement pressure in the unit of MPa; rho r is rock density in the unit of g / cm<3>; rho w is underground water density in the unit of g / cm<3>; theta is a fault inclination angle in the unit of degree, and H<fault> is a fault burial depth in the unit of m; Vshi is the argillaceous content of the small layer of the surrounding rock i outside the fault zone, delta Zi is the thickness of the small layer of the surrounding rock i outside the fault zone, and D is the vertical fault distance. According to the method, measured rock debris data are analyzed, and the data are easy to obtain; related research is carried out on the basis of the measured rock debris data, the result accuracy is high, and the fault plugging research cost is greatly reduced.

The invention discloses a shale gas well screening method and device, a terminal and a storage medium, and belongs to the technical field of oil and gas exploration and development. According to the method, the rock uranium content and the rock density of at least one shale gas well are obtained, the rock uranium content and the rock density of the at least one shale gas well are input into a target model, the rock uranium content and the rock density of the at least one shale gas well can be mapped to the organic carbon content of the at least one shale gas well through the target model, the target gas well with the highest organic carbon content is screened from the at least one shale gas well based on the organic carbon content of the at least one shale gas well, the target model can more accurately describe the organic carbon content based on the rock uranium content and the rock density, so that the organic carbon content obtained by mapping based on the target model has higher accuracy, and the target gas well obtained by screening also has higher accuracy.