85 results about "Density logging" patented technology

The invention discloses an underground physical characteristic prediction method and system combining seismic waves and drilling data, and relates to the technical field of geophysical exploration, and the method comprises the steps: collecting original seismic records, carrying out the preprocessing, obtaining a three-dimensional seismic data body, carrying out the complex channel analysis of the three-dimensional seismic data body, extracting the instantaneous amplitude, instantaneous phase and instantaneous frequency attributes, and carrying out the calculation of the instantaneous amplitude, instantaneous phase and instantaneous frequency attributes. Fault features are identified through a coherent body algorithm, an earthquake feature matrix is obtained, depth alignment and correction are carried out on density logging, interval transit time and neutron porosity curves of drill holes, and a standardized drill hole data table is generated; and based on the seismic feature matrix and the standardized drilling data table. According to the method, deep complementation of the earthquake macroscopic information and the borehole local truth value is realized through the geometric perception multi-modal graph neural network and the dynamic gating fusion mechanism, the problems of insufficient cross-modal feature fusion and misalignment of physical rules in the prior art are solved, and the prediction precision and reliability under complex geological conditions are remarkably improved.

The invention relates to the technical field of oil and gas drilling, and discloses a rock density data processing method and system based on machine learning, a terminal and a medium. The photoelectric absorption index, the compensation density and an energy window parameter output through rock density logging are used as input parameters, the photoelectric absorption index and the compensation density of a nominal value are used as labels, a sample library is established, a learning model is established according to the sample library, and an artificial intelligence algorithm is used for processing energy spectrum data measured by the lithologic density logging instrument. The density and photoelectric absorption index evaluation accuracy and the lithologic density logging measurement precision are improved under the condition of complex well holes and stratums, and the exploration requirements of complex reservoirs such as unconventional reservoirs are effectively met.

The invention relates to the technical field of logging equipment, in particular to a density logging instrument structure and an assembling method.The density logging instrument structure comprises a logging instrument shell, a column body and a gravity center deviation part, the gravity center deviation part enables the gravity center of the shell to deviate to one side of a well wall, a containing cavity is formed in the gravity center deviation part, and a shielding body is arranged in the cavity; the shielding body is provided with a first mounting hole for mounting a radioactive source and a radiation hole, a radioactive source protection piece is arranged in the radiation hole, a gravity center deviation part is provided with a protection cover plate, and a ray window cover plate opposite to the radiation hole is arranged on the protection cover plate; the invention further comprises an assembling method of the structure, such as the steps of fixing the shielding body, plugging the protection piece, installing the radioactive source, installing the protection cover plate and the like. The technical effects that the gravity center of the logging instrument structure deviates to one side of the well wall, the logging instrument can make contact with the well wall surface for measurement conveniently, the assembling method is safe and convenient, and the radioactive source can be effectively protected are achieved.

The application provides a calculation method of pore pressure of a tectonic compression formation. The calculation method of pore pressure of the tectonic compression formation comprises the following steps: S1, obtaining a density trend curve, and performing integral calculation on the density trend curve to obtain overburden pressure S V ; S2, determining total porosity POR of the formation based on acoustic logging, density logging, neutron logging or nuclear magnetic resonance logging; S3, analyzing characteristics of a target layer section to determine a tectonic compression coefficient ACm_C of the formation; S4, solving a pore pressure coefficient PP of a mudstone section based on a pore pressure model corrected based on the tectonic compression coefficient ACm_C; S5, determining a relationship between effective stress P eff and biot coefficient α and total porosity POR; and S6, inversely deducing a pore pressure coefficient of a reservoir section according to the relationship between the effective stress P eff and the total porosity POR. The application solves the problem of low calculation accuracy of the pore pressure calculation method in the prior art.

The invention discloses a formation pore pressure calculation method, system, equipment and medium, and the method comprises the steps: marking collected lithologic sections and geological stratification, and selecting at least one of collected seismic horizon velocity, density logging, acoustic logging and resistivity logging as sensitive parameters to establish a normal compaction trend line of a middle-shallow normal pressure section; a correction coefficient is adjusted by using the collected pressure measurement data, and finally, a traditional Eaton method formula is improved by using the adjusted correction coefficient, and a new formation pore pressure calculation formula is established; according to the method, the normal compaction trend line is fully utilized, the distortion of the normal compaction stratum is effectively inhibited while the abnormal pressure change is highlighted, the stability is better, the distortion is less, the pressure trend of the overlying stratum does not need to be calculated, parameters are few, the calculation efficiency is high, calculation can be carried out without logging data, the application range is wider, and the method is particularly suitable for low exploration areas without wells and with few wells.

This invention relates to a wave impedance inversion method, comprising the following steps: Step 1, collecting post-stack seismic data, sonic logging curves, density logging curves, lithology-representing curves, and reservoir interpretation results within the work area; Step 2, calculating wave impedance curves based on sonic logging and density logging curves; Step 3, assigning values ​​to various types of reservoirs to obtain formation identification codes; and reconstructing the wave impedance curves using the formation identification codes to obtain reconstructed wave impedance curves; Step 4, performing intersection analysis using the lithology-representing curves and the reconstructed wave impedance curves; Step 5, performing wave impedance inversion on the post-stack seismic data using the reconstructed wave impedance curves. This invention can directly identify effective energy storage with high accuracy.

The invention discloses a stratum density calculation method and device for variable energy window gamma density logging and a storage medium. The method comprises the steps that response energy spectrums of a gamma density logging instrument in different known stratum environments are obtained; changing the energy window boundary of the response energy spectrum, and obtaining density counts in different energy window ranges; calculating different density counts to obtain apparent density; performing benchmarking screening based on the apparent density and the stratum true density to obtain an optimal energy window combination; repeating the operation in different known stratum environments to record data, and connecting to obtain a stratum environment-energy spectrum-optimal energy window combined database; acquiring a to-be-detected stratum environment response energy spectrum; screening an existing response energy spectrum with the highest similarity with the response energy spectrum to be detected from the recorded response energy spectrums; and querying an optimal energy window boundary combination of the existing response energy spectrum with the highest similarity in the stratum environment-energy spectrum-optimal energy window combination database, and calculating the optimal energy window boundary combination to obtain a final calculation result. The method can improve the accuracy of stratum density calculation.

The application discloses a method for determining the position of drilling fluid leakage and calculating leakage parameters, which is used for finding the position of well leakage during drilling, calculating the leakage speed and leakage amount of drilling fluid, and estimating the leakage scale. The application describes the principle that the photoelectric absorption cross section Pe value of barite contained in the drilling fluid is abnormally high compared with other rocks, minerals and fluids, and the leakage position is accurately positioned by the characteristics of the high value of the Pe curve measured by the lithology density logging in the leakage well section, and the leakage speed is predicted by the correlation between the Pe logging value and the instantaneous leakage speed, and the leakage amount is calculated by combining the method of multi-mineral analysis with the actual content of barite in the drilling fluid. The method is simple and easy to operate, and the accuracy is reliable. Compared with the data provided by the field, the error of the leakage speed and the leakage amount calculated by the method is small, and the effect is good.

The application discloses a method, device and equipment for identifying sweet spots of shale oil in a salinized lake basin. The method comprises the following steps: firstly, determining a rock structure factor of a stratum based on a natural gamma curve, volume density logging data and skeleton density logging data of the stratum, so as to determine the lithology of the stratum and identify reservoir rock layers in the stratum based on the rock structure factor; then, determining a lamination index of the rock in the stratum based on electrical imaging logging data, so as to identify source rock layers in the stratum based on the lamination index; and finally, identifying a sweet spot development section of the shale oil in the salinized lake basin based on the reservoir rock layers in the stratum and the source rock layers in the stratum. The method can quickly identify the sweet spot development section of the shale oil in the target area, and provides a basis for later oil and gas development.

The application discloses a qualitative identification method for thin-layer mudstone interlayer in volcanic rock, which comprises the following steps: firstly, determining a mudstone section stably existing in the whole area through core observation and logging data, and taking the mudstone section as a standard section; secondly, selecting three curves (a neutron logging curve, an acoustic time difference logging curve and a density logging curve) responding best to the mudstone, standardizing logging curves of the standard section and the volcanic rock section in the whole area, and determining the peak value and the distribution range of the logging curves; selecting sample points with the best effect in the mudstone section and the volcanic rock section, taking the acoustic time difference logging curve as the horizontal coordinate, and taking the neutron logging curve and the density logging curve as the vertical coordinate respectively to establish a logging interpretation chart, qualitatively determining the identification standard of the mudstone and the igneous rock, and predicting the mudstone interlayer in the volcanic rock in a single well according to the chart. The application solves the problem of qualitative identification of the thin-layer mudstone interlayer in the volcanic rock, and provides reliable technical support for the analysis of the remaining oil potential of the igneous rock.

The invention relates to a shale gas horizontal well fracture pressure prediction method. The method comprises the steps of 1, multi-source data acquisition and intelligent depth correction, wherein logging data, element logging data, logging-while-drilling data, drilling engineering parameters and shaft track data of a target horizontal well section are acquired; 2, multi-scale feature enhancement: generating a high-dimensional feature sequence; step 3, nonlinear feature screening and mixed crustal stress prediction: screening out a key element combination, calculating an initial crustal stress profile through a traditional physical model based on sound wave and density logging data, and training a machine learning residual prediction model by taking the key element combination and other logging features as input to obtain a mixed crustal stress prediction model; adding the initial crustal stress profile and a residual error predicted value by predicting a residual error between a calculated value and an actual measured value of the physical model to obtain final predicted crustal stress data; and 4, calculating and verifying the fracture pressure: deducing the fracture pressure, and verifying a prediction result by using actual fracture test data.

This invention belongs to the field of oil and gas field development technology and discloses a method and equipment for predicting geostress based on the rotation trajectory and measurement data of a wellbore caliper. The method includes: analyzing the rotation trajectory of the wellbore caliper to find elliptical well sections and recording the major and minor axis measurements; calculating the dynamic Young's modulus and dynamic Poisson's ratio, and calculating the static Young's modulus and static Poisson's ratio using empirical formulas for dynamic-static conversion; obtaining the mud pressure based on construction data and calculating the overlying strata pressure through integration of density logging data; calculating the minimum horizontal principal stress based on the pump shutdown pressure; substituting the above parameters into the wellbore stress-strain formula, and obtaining the maximum horizontal principal stress through formula ratio, thus achieving geostress prediction for the target section. This invention can accurately calculate the biaxial stress difference and the maximum horizontal principal stress, effectively reducing the errors caused by wellbore irregularities and wellbore enlargement rate uncertainties in traditional stress relief methods, improving the accuracy of prediction results, and the testing procedure is simple and efficient.

This invention relates to the field of oil and gas field exploration and development, and discloses a logging identification method, system, equipment, and medium for hydrogen-rich reservoirs in clastic rocks. The method includes: identifying oil and gas reservoirs in clastic rock reservoirs based on differences in the conductivity of fluids within the reservoirs; identifying gas reservoirs in clastic rock reservoirs based on differences in the influence of oil and gas on the formation's elastic modulus; and identifying hydrogen-rich reservoirs based on differences in gas density within the gas reservoirs combined with differences in the gas's occurrence environment. The technical solution of this invention comprehensively utilizes logging methods such as shallow and deep resistivity logging, density logging, neutron logging, sonic logging, and natural gamma ray spectroscopy logging to identify hydrogen-rich reservoirs in clastic rock reservoirs, thereby improving the effectiveness and accuracy of hydrogen-rich reservoir identification.

The application discloses a method for determining biological silicon content in shale gas reservoirs based on lithology density logging data, and solves the problems of complex cost, inability to meet field scale, regional, low-cost evaluation and large calculation error of existing biological silicon content logging calculation methods. The method comprises the following steps: obtaining logging lithology density DEN, logging photoelectric absorption cross-section index Pe and logging natural gamma GR, establishing a ternary calculation equation based on the lithology density logging data, and then calculating the biological silicon content Si_toc in the shale gas reservoirs of the well to be interpreted. The method can be applied in coring wells, and has universal application value for all shale gas wells, and has smaller error and lower cost.

This invention belongs to the technical field of oil well logging equipment and discloses a four-detector lithology density electrode device and detection method, comprising: a housing assembly, inside which are arranged sequentially a first far detector, a first near detector, a source chamber, a second near detector, and a second far detector; the distances of each detector from the source chamber, from largest to smallest, are: second far detector, first far detector, first near detector, and second near detector. This invention uses four detectors, namely the first far detector, the first near detector, the second far detector, and the second near detector. Each detector acquires density logging curves and lithology logging curves by collecting data. Moreover, if any one detector fails, the remaining three detectors can still generate two volumetric density values ​​and at least one formation photoelectric absorption index cross-section value, obtaining the volumetric density and formation photoelectric absorption index cross-section. The entire machine can still guarantee measurement accuracy and perform normal well logging.

The invention relates to the technical field of oil well logging, and provides a magnetophilic density source bin structural design which comprises an instrument shell, a source chamber pin, a magnetophilic cover plate, a fastening screw, a source chamber body, a density source, a source bin screw and a ray window, a T-shaped groove is formed in the magnetophilic cover plate, the source chamber body is arranged in the T-shaped groove, and the density source is arranged in the T-shaped groove. The source chamber main body is fixed on the paramagnetic cover plate through the fastening screw, and the density source is arranged in the source chamber main body; the upper side of the paramagnetic cover plate is rotatably connected with the instrument shell through the source chamber pin, and the lower side of the paramagnetic cover plate is arranged on the instrument shell through the source chamber screw; the ray window is arranged on the instrument shell through a rolling shaft pin, the ray window is located below the source chamber main body, the ray emitting direction of the ray window is tightly attached to the stratum, and the opening direction of the source chamber main body is back to the stratum. The method has the effects of improving the safety of density logging and reducing the well falling probability of the source chamber.

The invention relates to a source bin structure and a density logging instrument, the source bin structure comprises a source bin body, the source bin body is used for being fixedly connected with a logging instrument body, the source bin body is provided with a mounting hole, the axis of the mounting hole is parallel to the axis of the logging instrument body, a source box assembly is slidably connected in the mounting hole, and a radioactive source is mounted in the source box assembly. A ray emitting window is arranged at the position, corresponding to the radioactive source, of the source bin body, and an emitting window plug is fixedly connected to the ray emitting window. The source bin structure can be suitable for a small-diameter logging instrument, and is convenient to install and convenient to popularize and operate on site; the source box disclosed by the embodiment has the advantage of being convenient to take out, so that the radioactive source can be conveniently taken out; according to the embodiment, the ray shielding effect is good, and the center of the radioactive source is close to the ray emergent window.

The invention belongs to the technical field of formation pore pressure acquisition, and discloses a pore pressure acquisition method and system based on a depth trend line and formation factors, and the method comprises the steps: collecting well leakage, gas cut and overflow in a drilling process, and re-pressing and static pressure data in an oil testing process, and fitting a regression pressure trend line; drawing an engineering pore pressure geological factor interpretation read map, reading interval transit time and density logging values, and calculating formation factors; forming a pressure factor linearly related to the formation pore pressure by combining the regression pressure trend line and the formation factor; and drawing a formation pore pressure-pressure factor cross plot, carrying out linear regression fitting, and calculating the equivalent density of the formation pore pressure. According to the method, various pressure data (such as well leakage, gas cut, overflow and re-pressure and static pressure data in the oil testing process) in the drilling process are collected, the data are used for logarithmic regression fitting, and the obtained pressure trend line can more accurately reflect the change trend of the formation pore pressure along with the depth.

The utility model relates to the technical field of cement bond logging instruments, and discloses a cement bond logging instrument with an eccentricity correction function, which comprises a cement bond logging instrument body. The cement bond logging instrument body is composed of an electronic circuit module, a sound wave generator, a sound insulator, a sound wave logging receiver, a sound amplitude logging receiver and a sound wave variable density logging receiver. The threaded block is spirally rotated, the threaded block drives the adjusting sleeve to move downwards on the outer wall of the L-shaped guide rod through cooperation of the limiting slide and the guide groove, and the adjusting sleeve drives the four arc-shaped positioning plates to expand outwards through the multiple connecting rods and the multiple multi-section guide telescopic rods. Four arc-shaped positioning plates are arranged in the inner cavity of the cased well, and rolling balls on the outer walls of the four arc-shaped positioning plates abut against the inner wall of the cased well, so that the cement bond logging instrument is limited, it is guaranteed that the cement bond logging instrument is located in the middle of the inner cavity of the cased well, the conditions of inclination and eccentricity of the cement bond logging instrument are avoided, and the accuracy of measured data of the cement bond logging instrument is improved.

The application discloses a porosity calculation method and system for complex reservoirs, which comprises the following steps: selecting a marker layer, and performing preliminary correction on original neutron and density logging curves of a target layer by using deviation analysis according to skeleton neutron values and skeleton density values of the marker layer; based on core analysis test data of the target layer, core data is homed in the preliminary corrected neutron and density logging curves, and a fusion analysis chart is formed based on this; the fusion analysis chart is corrected in neutron values by using a neutron multiplication factor initial value, and a neutron multiplication factor final value is determined by comparing a formation porosity calculation value obtained by using the corrected neutron and density with a formation porosity measurement value; and the original neutron and density logging curves are comprehensively corrected by using the preliminary correction amount and the neutron multiplication factor final value, so that the formation porosity of a single well is obtained.

The invention relates to a compressibility evaluation method based on multi-source crack imaging logging data fusion, which comprises the following steps of: acquiring multi-source logging data and identifying well wall cracks, realizing cross-scale acquisition of near-well crack and far-well crack information, and forming a crack basic data set; constructing a multi-source logging data fusion and crack three-dimensional network, and fusing well wall crack parameters of a near-well area and crack imaging results of a far-well area to represent crack space distribution in a target detection range by taking a shaft as a center; rock mechanical parameters based on sound wave and density logging are calculated; and calculating a brittleness index and a compressibility index, integrating the brittleness index, the fracture network density, the development degree and the ground stress difference ratio, constructing a reservoir fracture comprehensive compressibility evaluation model, and completing the evaluation of the fracture compressibility. The near-well electrical imaging data and the far-well acoustic imaging data are deeply fused, the rock mechanical parameters are fused and calculated, and the problem that in the prior art, crack features and the rock mechanical parameters are mutually separated is effectively solved.

Systems and methods for determining a calibrated vertical seismic profile (VSP) using a distributed acoustic sensing (DAS) system in a borehole are presented. The method includes obtaining a density log and an acoustic slowness log of the borehole (108); determining a first impedance from the density logging curve and the acoustic slowness logging curve, i.e., a DAS impedance (DIL) curve from the logging curve; obtaining a VSP data set in the borehole (108); for each of the plurality of gauge lengths, a second impedance, i.e. A DAS (DIV) curve from vibration, is determined from the VSP dataset of the plurality of gauge lengths, and a fit between the DIV curve and the DIL curve is determined by using a mismatch functional for each of the plurality of depth adjustments. The method also includes determining a calibrated VSP by applying the preferred depth adjustment to the VSP dataset.

This invention belongs to the field of seismic comprehensive interpretation research technology and discloses a lithofacies identification method based on difference analysis. First, it calculates the difference data of P-wave velocity logging curves, S-wave velocity logging curves, and density logging curves. Using the drilling lithofacies type, the Gaussian Mixture method is used to perform cluster analysis on the difference data of P-wave velocity logging curves, S-wave velocity logging curves, and density logging curves to obtain the well logging lithofacies data. Based on the well logging lithofacies data, the lithofacies depth trend is analyzed. Using the lithofacies depth trend as a constraint, a Bayesian method is used to predict the spatial distribution of well logging lithofacies. This invention also provides a lithofacies identification device, equipment, and storage medium based on difference analysis. This invention can accurately identify lithofacies, improve the efficiency of identification work, and has good application effects and promotion prospects.

This invention discloses an intelligent lithology density logging tool, relating to the field of logging tool technology. It includes a housing, with a spectrometer installed in the central region of the housing. A mounting shell is rotatably connected to the bottom of the housing, driven by a motor installed in a cavity at the bottom of the housing. Sealing and drainage mechanisms are installed at both ends of the spectrometer within the housing, and a cleaning mechanism is installed within the mounting shell. The sealing and drainage mechanism includes a rotating shaft rotatably connected inside the housing. A through-groove is formed on the surface of a sealing plate, and a baffle plate is rotatably connected to the inner wall of the through-groove via a torsion spring. A sealing support assembly is provided below the cylinder, enabling complete drainage of mud from the sealed area. This fundamentally solves the problem of mud obstructing light propagation, leading to discrepancies between detection results and actual values, and also addresses the issue of lithology identification and density measurement deviations caused by mud obstruction on the well wall in traditional logging equipment.

This invention provides a method and system for fluid identification in tight sandstone gas-bearing formations. It employs a combined three-porosity logging method, a combined nuclear magnetic resonance (NMR) logging and density logging method, and a combined NMR logging and three-porosity logging method for fluid identification in tight sandstone gas-bearing formations. The method constructs multiple gas-bearing formation sensitive factors through theoretical analysis, amplifying the differences between gas-bearing formations and building fluid identification charts. In the interpretation of new target layers, fluid discrimination is performed based on each chart, and the final interpretation result is determined using the chart consistency rate method or the absolute majority voting method. The fluid sensitive factors constructed in this invention, and the cross-plots built based on these factors, can effectively distinguish fluid types. The comprehensive discrimination strategy organically combines the results of multiple methods, eliminating the limitations of any single method. The interpretation results have been verified by oil testing, showing a significantly improved consistency rate.

The application provides a device and method for determining glauconite content, a model and a construction method and application thereof, and the determining method comprises the following steps: determining and optimizing first basic parameters by using conventional logging data in combination with regional geological data, the first basic parameters comprising PE sh , rho sh and V sh ; obtaining second basic parameters based on common sedimentary rock mineral logging characteristic values, the second basic parameters comprising PE qz , PE gl , rho qz , rho gl and rho f ; obtaining third basic parameters based on lithology density logging data, the third basic parameters comprising PE and RHOB; and substituting the first basic parameters, the second basic parameters and the third basic parameters into a calculation model of the glauconite content in the sandstone to obtain V gl , V qz and the application has the advantages of economy, rapidness, rich information, high accuracy, convenience in operation and the like by quantitatively calculating the glauconite content in the sandstone through scientific theoretical methods.

The application discloses a high-resolution P-wave time difference extraction method, device and equipment, and the method comprises the following steps: extracting a low-resolution P-wave time difference curve and a P-wave arrival time curve of a target well based on monopole array waveform data of the target well, and extracting a low-resolution S-wave time difference curve of the target well based on dipole array waveform data of the target well; constructing a borehole earth numerical model of the target well based on a caliper logging curve, a density logging curve and the low-resolution P-wave time difference curve and the low-resolution S-wave time difference curve of the target well, and determining a simulated monopole P-wave waveform curve of the target well based on the borehole earth numerical model; performing frequency-wave number domain analysis based on the simulated monopole P-wave waveform curve to determine a high-order P-wave frequency band distribution range; performing filtering processing on the measured monopole array waveform data based on the high-order P-wave frequency band distribution range to obtain high-order P-wave array waveform data; and determining a high-resolution P-wave time difference based on the high-order P-wave array waveform data and the P-wave arrival time curve.

The present invention proposes a method, system, and apparatus for calculating an unconventional reservoir brittleness indicator curve. The method comprises: determining the shale content based on a well logging data curve and reservoir rock physical parameter information; and determining the brittleness indicator curve based on the shale content and well logging porosity. The method, system, and apparatus for calculating an unconventional reservoir brittleness indicator curve of the present invention, based on conventional P-wave logging, density logging, and porosity logging information, integrates rock physical analysis to construct a brittleness indicator curve calculation formula, and implements brittleness indicator parameter calculation and evaluation under conventional logging conditions. This method does not rely on S-wave logging information and is not affected by human factors. It is a highly applicable and accurate brittleness index extraction method. Conducting shale gas reservoir brittleness evaluation based on this method will effectively improve the accuracy of shale gas reservoir fracturing evaluation and reduce the risks of exploration and development.

The invention discloses a simulated annealing standardization correction method and system for density logging data, and belongs to the technical field of logging data processing. Comprising the steps of collecting density logging data of a standard well and original density logging data of a to-be-corrected well, preprocessing the original density logging data of the to-be-corrected well, establishing density data histogram distribution based on a linear mapping model, establishing a histogram overlapping comparison evaluation system, and calculating a comprehensive matching score. Optimizing calculation is conducted on the linear mapping model based on a simulated annealing algorithm, linear transformation parameters are automatically optimized, the optimal parameters are applied to full-well-section density data correction, and comparison between original density data and an anti-normalization processing result is achieved through anti-normalization processing. The method effectively overcomes the defects that a traditional method depends on artificial experience and is low in correction precision, data quality and processing efficiency are remarkably improved, and a reliable data basis is provided for reservoir fine evaluation.

The invention discloses a passive density correction method applied to coal seam measurement, and belongs to the technical field of petroleum and natural gas development. The method comprises the following steps: firstly, obtaining the influence of coal seams with different densities on a passive density measurement result through a numerical simulation method; then, calculating the apparent density of the coal seam by utilizing an existing density data processing method, and calculating a passive density error caused by the coal seams with different densities according to the difference between the apparent density and the real density; secondly, establishing a mathematical relationship between the passive apparent density and a passive density error, and forming a passive density coal seam argillaceous correction formula; and finally, substituting the apparent density of the coal seam into a coal seam density correction formula to obtain a density correction value, and superposing the density correction value to a passive density result to obtain relatively accurate coal seam density. According to the method, the measurement precision of passive density logging in the coal seam is improved, and the application scene of the method in the coal seam is expanded.