95 results about "Effective porosity" patented technology

The invention relates to a lacustrine facies shale conductive model considering organic matter influence and a saturability evaluation method, and belongs to the technical field of unconventional oil and gas reservoir oiliness evaluation, and the method comprises the following steps: 1) representing fluid information in a shale sample based on a pressure-maintaining closed sample and a two-dimensional nuclear magnetic resonance technology; 2) according to the organic carbon content and the clay content of the shale, dividing the lithology type of the lacustrine facies shale, and analyzing the relation between different lithology resistivity values and the porosity of free water and bound water; 3) selecting a siltstone interlayer sample, and inversely calculating a cementation index and a saturation index of the inorganic pore conductive network; 4) establishing a lacustrine facies shale parallel conductive model, and calibrating rock-electricity parameters according to lithology; 5, a lithology discrimination chart, a TOC prediction model, a bound water content prediction model and an effective porosity calculation model are established, and the oil saturation is explained according to different lithologies in combination with the lacustrine facies shale parallel conduction model.According to the method, accurate shale reservoir fluid information is provided, and a brand new thought is provided for rock electrical parameter calibration.

The invention relates to the field of oil and gas field exploration and development, in particular to a shale oil dessert well logging evaluation method and device based on source-reservoir coupling characteristics, and the method comprises the steps: determining the reservoir quality according to the effective porosity and effective thickness of a shale oil reservoir in a research area; the effective porosity is greater than a preset porosity lower limit threshold; evaluating the quality of each hydrocarbon source rock stratum section according to the effective points of the total organic carbon content of the kerogen in the research area, the effective thickness of the layer section corresponding to each effective point and the total organic carbon content of the kerogen of the effective point; according to the coupling relation between the reservoir quality and the quality of the hydrocarbon source rock stratum section within the estimated longitudinal distance range of the position of the effective point of the total organic carbon content of the kerogen; according to the coupling relation, shale oil desserts within the longitudinal distance range are evaluated and estimated. On the basis of hydrocarbon source rock quality classification, reservoir quality classification and a source-reservoir coupling relationship, a foundation is laid for accurate classification evaluation of shale oil dessert development sections.

The present description relates to the field of oil and gas field exploration and development, and in particular, to a shale oil sweet spot logging evaluation method and apparatus based on source-reservoir coupling characteristics. The method comprises: on the basis of the effective porosity and effective thickness of a shale oil reservoir in a research area, determining reservoir quality, wherein the effective porosity is greater than a preset porosity lower threshold; on the basis of effective points of kerogen total organic carbon content in the research area, the effective thickness of an interval corresponding to each effective point, and the kerogen total organic carbon content of each effective point, evaluating the quality of source rock intervals; on the basis of an estimated longitudinal distance range of the positions where the effective points of kerogen total organic carbon content are located, determining a coupling relationship between the reservoir quality and the quality of the source rock intervals; and on the basis of the coupling relationship, evaluating a shale oil sweet spot within the estimated longitudinal distance range.

The invention discloses a shale reservoir classification evaluation method based on machine learning and optimal fractal attributes, and relates to the technical field of shale reservoir evaluation. Comprising the following steps: calculating fractal attribute indexes of a T2 spectrum, obtaining a new clustering label, obtaining optimal fractal attribute values, obtaining a final classification label, applying a final classification basis to all optimal fractal attribute values of a target well, and obtaining a new classification result; multi-fractal calculation is carried out on T2 spectrum original data obtained through nuclear magnetic logging, effective porosity data obtained through combination of corresponding well section closed coring data is taken as the basis, after effective porosity of different degrees is classified, systematic machine learning training is carried out on fractal attributes corresponding to each category, and fractal fractal data are obtained. And a set of classification interval of fractal attribute values mainly based on the fractal attribute with the maximum influence degree is obtained and is applied to all fractal attribute values of the target interval, so that the shale reservoir can be accurately classified and evaluated.

The invention relates to the technical field of tunnel engineering safety monitoring, in particular to a karst rock stratum tunnel health diagnosis method, device and equipment and a storage medium. Comprising the steps that whether catastrophe nodes matched with tunnel multi-source sensing data obtained in real time exist or not is judged by searching a karst-lining-surrounding rock coupling knowledge graph; if yes, diagnosis is carried out according to a node embedded karst water-rock coupling mechanism; and if not, calling a preset karst catastrophe fusion model to carry out online learning and dynamic diagnosis, and adding catastrophe nodes in the knowledge graph. According to the fusion model, characteristics such as karst water chemical ion concentration change rate, surrounding rock effective porosity mutation gradient and lining back cavity volume growth rate are extracted, karst water inrush and mud inrush risk probability distribution is output based on multiple neural network model parallel coupling architectures, and high-risk perception data are automatically screened out or marked according to a threshold value. The karst water inrush and mud inrush risk of the karst stratum tunnel can be accurately identified, and real-time early warning can be carried out.

The invention discloses a method for determining porosity of a shale oil sample in an effective pore space. The method mainly solves the problem that the porosity of an effective storage space cannot be accurately measured due to cracks caused by unsmooth oil-gas separation of the existing oil-containing shale and loss of clay water. The method is characterized by comprising the following steps: S1, preparing a shale sample; s2, putting the sample into a saturated solution for self-absorption saturation, and recording the self-absorption saturation time; s3, measuring the crane scale mass of the sample in the saturated liquid and the wet sample mass of the sample full of the saturated liquid, measuring the density of the saturated liquid, and calculating the total volume of the sample; s4, performing oil removal, ventilation and dehumidification on the sample; s5, measuring the mass of a dry sample and the volume of a sample skeleton, and measuring the mass of particles and dust in the sample bag; and S6, calculating the porosity of the shale sample. According to the method, the influence caused by cracks generated by dehydration of the sample is eliminated, the effective porosity of the shale oil sample in which the clay adsorbed water is retained in situ and the pore water is removed can be accurately determined, the experimental period is short, and the accuracy is high.

The invention discloses a subdivided lithologic variable T2 cutoff value effective hole calculation method and system and electronic equipment, and belongs to the technical field of complex lithologic oil and gas reservoir well logging evaluation. Based on a glutenite reservoir of nuclear magnetic resonance well logging information, on the basis of accurate division of lithology, influence factors of rock components and pore structures are comprehensively considered, and the effective holes of the lithologic variable T2 cutoff value are calculated; according to the method, effective porosity calculation models of different nuclear magnetic T2 cutoff values are established according to lithology, a method of fitting a formula according to lithology is adopted, a large amount of nuclear magnetic experiment calibration is not needed, and effective porosity calculation of complex lithology can be realized by utilizing conventional logging, nuclear magnetic resonance T2 spectrum data and experimental pore structure data; compared with a method for calculating the effective porosity through a fixed T2 cut-off value, the method has the advantages that the calculation precision of the effective porosity of the reservoir is greatly improved, key parameters can be provided for reservoir physical property evaluation and saturation calculation, convenience and rapidness are achieved, rapid large-scale application in production is facilitated, and good universality and popularization value are achieved.

The invention relates to the technical field of nuclear magnetic resonance logging, aims to solve the problem that a method for jointly correcting a nuclear magnetic resonance logging T2 spectrum by integrating multiple factors does not exist at present, and provides a gas-containing shale nuclear magnetic resonance relaxation time spectrum correction method, a storage medium and a device. The method comprises the steps of obtaining target layer information; determining a T2 spectrum correction position; factors influencing the difference between the nuclear magnetic porosity and the conventional logging porosity are analyzed, and the influence of the factors on the nuclear magnetic resonance logging T2 spectrum is corrected according to the factors; respectively fitting each spectrum peak of the T2 spectrum through a Gaussian distribution curve, completing correction of each factor on the spectrum peak, and obtaining a final corrected nuclear magnetic offset T2 spectrum; superposing the porosity components of the corrected T2 spectrum Gaussian distributions of the fluid peaks at the corresponding distribution points to obtain corrected effective porosity and total porosity; according to the invention, automatic correction of the nuclear magnetic resonance logging T2 spectrum can be realized.

The invention belongs to the technical field of unconventional shale oil and gas exploration and development, and discloses a shale reservoir physical property and oiliness controlled factor analysis method. Comprising the following steps: determining a reservoir classification standard through a one-dimensional nuclear magnetic experiment and a mercury injection experiment phase; and performing lithogenous phase statistics on the pore ratio and effective porosity controlled factor analysis. And analyzing fluid properties of different lithofacies based on two-dimensional nuclear magnetic oiliness explanation. And analyzing oiliness controlled factors. By analyzing the controlled factors of the physical property and oiliness of the shale reservoir, the sweet spot distribution can be determined, the shale oil momentum can be determined, and the shale oil productivity can be improved.

The invention relates to the field of coal mine safety mining and underground water control, and particularly discloses an intelligent drainage and pressure reduction comprehensive treatment method based on dynamic drainage density optimization, which comprises the following steps: S1, arranging a monitoring section fixed-distance grid array, and determining point location and hole sealing requirements; s2, adopting a structured mesh to subdivide the three-dimensional model; s3, describing spatial correlation between aquifer parameters and effective porosity by using a spherical variation function model, and performing universal Kriging interpolation in combination with covariables to generate a three-dimensional parameter field; s4, solving a Darwest equation based on a finite difference method to establish a three-dimensional water flow model; s5, correcting a traditional water inrush coefficient formula by using a rock mass integrity coefficient, and setting a third-level early warning threshold value; s6, determining double threshold values of the safe water level and the ecological water level; s7, well density calculation is carried out, and a function is constructed; and S8, establishing a staged drainage scheme to form an ecological regulation and control strategy. According to the method, the drainage amount can be accurately and dynamically regulated and controlled, the water inrush risk is reduced, and ecological disturbance is reduced.

The invention discloses an effective porosity and heavy oil saturation evaluation method and related equipment, and the method comprises the steps: calculating a plurality of groups of porosity components through collected echo measurement values, inverting a T2 spectrum by combining a dynamic logarithm spectrum splicing mode with the porosity components, and finally unfolding the T2 spectrum obtained through inversion by adopting MRIL-P or MRT to obtain the effective porosity. According to the method, a T2 spectrum is inversely generated in a logarithm spectrum splicing mode based on analysis of an MRIL-P or MRT spectrum unfolding principle; the problems of low precision of bound peaks and information loss before a certain moment can be solved by adopting a logarithmic spectrum splicing mode, so that the effective porosity is accurately obtained; by comparing the effective porosity obtained by the method with the helium porosity, the error is reduced to be within 1.5%, and the porosity explanation precision is obviously improved; by adopting the method, the technical problem that the effective porosity of the three-low characteristic region cannot be accurately calculated by the existing evaluation measure can be solved.

The invention discloses a shale oil sample oil-water saturation determination method based on a dry distillation technology. The problem that the oil-water saturation of the shale oil reservoir rock sample is difficult to accurately measure by using a single sample is solved. Comprising the following steps: S1, preparing a full-diameter flaky shale sample to be detected; s2, performing a sample pore water removal experiment on the tested shale sample; s3, carrying out a low-temperature dry distillation water recovery rate measurement experiment; s4, carrying out low-temperature dry distillation, and measuring the mass of the moisture trap and the shale sample; s5, measuring the total volume of the shale sample; s6, removing oil from the shale sample; s7, dehumidifying the shale sample subjected to oil removal; s8, measuring the volume of the skeleton; s9, correcting and measuring the total volume of the fracture sample; and S10, calculating the oil-water saturation of the shale sample. According to the method, on the basis of a low-temperature dry distillation technology, the pore water of the shale sample and the oil-water saturation of the shale oil sample with the effective porosity can be determined on the same sample, and the determination and analysis method is convenient, rapid and accurate.

The embodiment of the invention discloses a pore flow capacity determination method and device, electronic equipment and a storage medium. The method comprises the following steps: aiming at a target rock sample acquired from a target reservoir, determining the total porosity and the effective porosity of the target rock sample, and determining the mineral content and the mineral Young modulus respectively corresponding to each mineral contained in the target rock sample; and according to the total porosity, the effective porosity, and the mineral content and the mineral Young modulus corresponding to each mineral, determining the pore flow capacity of the target reservoir. According to the technical scheme provided by the embodiment of the invention, the pore flow capacity of the tight gas reservoir can be determined.

The present invention relates to a lacustrine shale conductive model and saturation evaluation method considering the influence of organic matter, belonging to the technical field of oil content evaluation of unconventional oil and gas reservoirs, including: 1) characterizing fluid information in shale samples based on pressure-maintained sealed samples and two-dimensional nuclear magnetic resonance technology; 2) classifying lacustrine shale lithology types according to shale organic carbon content and clay content, and analyzing the relationship between resistivity values ​​of different lithologies and free water and bound water porosity; 3) selecting siltstone interlayer samples, and inversely calculating the cementation index and saturation index of the inorganic pore conductive network; 4) establishing a lacustrine shale parallel conductive model, and calibrating rock electrical parameters by lithology; 5) establishing a lithology and lithology discrimination chart, a TOC prediction model, a bound water content prediction model and an effective porosity calculation model, and combining the lacustrine shale parallel conductive model to interpret oil saturation by different lithologies. The present invention provides accurate shale reservoir fluid information and provides a new idea for rock electrical parameter calibration.

The present application relates to the technical field of seepage mechanics, and particularly relates to a conical sealing surface leakage rate calculation method based on Darcy's law, comprising the following steps: a W-M function is used to simulate the random topography of the workpiece surface at a microscale, and a normalization method is used to generate surface point cloud data meeting roughness requirements; according to the surface point cloud data, a contact mechanics model is used to solve the change law between the contact state and the external load, and according to the Hertz contact theory, the contact between the rough surfaces is reconstructed as the contact between a rigid plane and a flexible rough surface; the surface is discretized into a three-dimensional grid model, the effective porosity is screened and calculated by using the connected domain discrimination method; a micro-leakage rate calculation method for the conical sealing surface in the flared pipe joint is obtained based on the effective porosity and the seepage mechanics theory algorithm; the leakage rate of the conical sealing interface is calculated, and the sealing performance of the interface is quantitatively evaluated. The present application improves the comprehensiveness and accuracy of the sealing performance evaluation.

The invention discloses a method and device for predicting the effective porosity of a tight sandstone reservoir, and belongs to the technical field of oil and gas exploitation. The method comprises the following steps: determining a corresponding relation between effective porosity and Young modulus according to the effective porosity and Young modulus of a plurality of depth points in a target compact sandstone reservoir; according to the Poisson's ratio attribute body and the bulk modulus attribute body of the target compact sandstone reservoir, a Young modulus attribute body of the target compact sandstone reservoir is obtained, and data points in the Poisson's ratio attribute body and the bulk modulus attribute body are in one-to-one correspondence; based on the corresponding relation between the effective porosity and the Young modulus and the Young modulus attribute body of the target compact sandstone reservoir, the effective porosity attribute body of the target compact sandstone reservoir is obtained. According to the method, accurate prediction of the effective porosity of the tight sandstone can be realized, and technical support is provided for development of a tight sandstone reservoir.

The present application discloses a method, device and computing equipment for determining the lower limit of effective reservoir physical properties. The method includes: obtaining a first transverse relaxation time spectrum of any measurement point obtained by performing nuclear magnetic resonance logging on the target formation; calculating the first effective porosity of the measurement point based on the first transverse relaxation time spectrum of the measurement point; extracting the second transverse relaxation time spectrum of the invading mud from the first transverse relaxation time spectrum of the measurement point, and calculating the second effective porosity of the measurement point based on the second transverse relaxation time spectrum; establishing a first intersection diagram of the first effective porosity and the second effective porosity based on the first effective porosity and the second effective porosity of different measurement points; determining the inflection point of the first intersection diagram, and using the first effective porosity corresponding to the inflection point as the lower limit of the effective porosity of the target formation. This solution can improve the accuracy of determining the lower limit of effective reservoir physical properties, lower the data threshold, and improve the efficiency of determining the lower limit of effective reservoir physical properties.

The present invention discloses a method and application for determining the effective porosity of shale, taking into account both lamellar fractures and matrix pores. The method includes conducting a helium porosity measurement experiment on a shale sample until a first set time is reached, obtaining multiple experimental data comprising pairs of experimental time and porosity. Based on a mathematical model of shale effective porosity and experimental time, the experimental data is fitted to obtain a fitting relationship between the effective porosity of the rock sample and the experimental time. The effective porosity, matrix porosity, and lamellar fracture porosity of the rock sample are then determined based on the rock sample selection direction and the fitting relationship. This method can achieve the separate quantification of matrix porosity and lamellar fracture porosity of shale samples, providing key parameters for pure shale oil resource evaluation, sweet spot prediction, and reserve submission.

The invention discloses a method for determining well logging skeleton parameters of talc minerals and effective porosity of formations, which is characterized by comprising: obtaining the contents of various minerals in core samples at different depths of a coring well and the well logging curve of the coring well; establishing a calculation formula between the contents of various minerals at corresponding depths and the well logging values ​​on the well logging curve; solving the calculation formula according to the well logging skeleton parameters of known minerals to obtain the well logging skeleton parameters of the talc minerals; and solving the problem that the well logging skeleton parameters of the talc minerals are currently unknown and cannot be determined by a pure rock measurement method.

The application provides a shale free oil saturation calculation method and device. Through obtaining the surface temperature, geothermal gradient and spectrum of shale, the logging interpretation data is calculated by using a functional relationship; then a training data set and a verification data set are established, the verification data set is sent to a machine learning algorithm model trained by using the training data set, and a data learning result is obtained; based on the data learning result and the spectrum without three-peak characteristics, free oil signal data in the spectrum without three-peak characteristics is determined, the free oil signal data is fitted, and a normal distribution expression of the free oil spectrum is obtained; and the ratio of the free oil porosity component and the effective porosity component is used to calculate the free oil saturation of the target shale, so that the problems of high data acquisition cost and large calculation error in the existing shale free oil saturation calculation method are solved.

The application provides a shale pore fluid type and porosity determination method, device and medium. The method obtains nuclear magnetic resonance logging data of shale in a target interval, performs T2 spectrum component stripping processing on the data, obtains a plurality of corresponding nuclear magnetic resonance logging T2 sub-spectra, determines pore fluid type calibration characteristics according to differences in T1-T2 spectrum diagrams of shale with different clay mineral contents and under different core saturation states, calibrates the fluid type of the plurality of nuclear magnetic resonance logging T2 sub-spectra based on the pore fluid type calibration characteristics, obtains the fluid type corresponding to each nuclear magnetic resonance logging T2 sub-spectrum, and then determines the effective porosity and movable fluid porosity of the shale based on the plurality of nuclear magnetic resonance logging T2 sub-spectra and the corresponding fluid type. The method improves the calculation accuracy of the porosity, and provides a simple and reliable method for fluid type discrimination and porosity calculation of logging that only measures one-dimensional nuclear magnetic resonance logging and has no coring nuclear magnetic resonance experiment.

The invention discloses a shale oil saturation calculation method and device, a medium and a program product, and relates to the field of petroleum and natural gas exploration, and the method comprises the steps: obtaining geological parameters of a shale oil layer to be logged; inputting the geological parameters into a pre-constructed water saturation calculation model, and outputting the water saturation of the shale oil layer; the construction process of the water saturation calculation model comprises the following steps: establishing a Simmen equation between the clay resistivity and the clay mass fraction, and a Simmen equation between the stratum resistivity and the sandstone resistivity; establishing Archie equations of the sandstone resistivity, the water saturation, the formation water resistivity and the effective porosity, and constructing a water saturation calculation model for calculating the water saturation in combination with the Simmen equation and the Archie equation; and calculating the oil saturation of the shale oil layer according to the water saturation. The method solves the problem that the calculation precision of the oil saturation of shale oil is reduced due to the fact that the logging interpretation method does not consider the influence of the conductivity of clay on the formation resistivity.

The invention discloses a method and system for calculating the shale gas resource quantity in a complex tectonic region, and belongs to the field of shale gas.The method comprises the steps that S1, three-dimensional seismic data, logging data and core analysis data in the complex tectonic region are collected, and high-frequency denoising and wave impedance inversion are conducted; s2, generating a fracture distribution model by using a fracture structure quantitative description algorithm, and establishing a three-dimensional geologic structure model in combination with logging lithology recognition; s3, high-precision stratum thickness correction is carried out on the three-dimensional geological structure model, and effective stress distribution of the reservoir is calculated through stress field numerical inversion; s4, calculating effective porosity and permeability parameter distribution of the reservoir in combination with a porosity-permeability nonlinear coupling equation; s5, measuring to obtain pore structure parameters, and superposing to form a reservoir physical property comprehensive model; s6, performing super-resolution volume modeling on the model to generate a three-dimensional reserve model; and S7, calculating the unit resource quantity grid by grid based on the three-dimensional reserve model and adding the unit resource quantity. The method has the beneficial effect that the accuracy and stability of shale gas resource quantity calculation in the complex tectonic area are improved.

The present application belongs to the technical field of petroleum and natural gas geology and exploration and development engineering, and particularly relates to a method and system for identifying fluid properties of high-salinity tight reservoirs. The macroscopic capture cross-section theoretical value under the condition of high-salinity formation water is calculated by using mineral content, then the difference value between the macroscopic capture cross-section theoretical value and the measured value of the macroscopic capture cross-section is used as a sensitive factor for oil-bearing property judgment, and the difference value and the effective porosity are used to form a fluid property identification chart, so that the fluid properties of tight oil reservoirs under the condition of high-salinity background can be accurately identified; the ratio of the relative yield of chlorine element to the effective porosity is used as a salt-bearing sensitive factor, and the salt-bearing sensitive factor and the effective porosity are used to form a salt-bearing evaluation chart, so that the salt-bearing degree of the sweet spot section can be judged, and it is determined whether oil testing is necessary. The method can accurately identify the fluid properties under the condition of high-salinity tight reservoir background, and give oil testing suggestions.

The invention relates to the technical field of oil field oil reservoir development models, in particular to a dry rock model building method for a high-water-cut-period reservoir of an oil field. According to the dry rock model building method for the high-water-cut-period reservoir of the oil field, well drilling and well logging work is carried out on a target reservoir, data are collected, a curve is drawn through the data, consistency correction is carried out, total porosity is calculated according to the corrected data curve, and irreducible water porosity is obtained by subtracting effective porosity. And adding the obtained bound water porosity into dry clay data to obtain wet clay data, then combining the wet clay data with core data to establish a rock skeleton model, and then combining the rock skeleton model with the effective porosity to form a new dry rock model. According to the dry rock model building method for the high-water-cut-period reservoir of the oil field, the bound water porosity is calculated and added into the dry clay data to obtain the wet clay data, and the influence of long-time water injection exploitation on the structure in the reservoir is considered; and the reservoir sand body prediction precision and the fluid identification capability by using the longitudinal and transverse wave curves are improved.

The invention discloses a method for predicting oil sand seepage characteristics through a two-dimensional digital core. The method comprises the following steps: step 1, acquiring a core grayscale image of oil sand by using an environmental scanning electron microscope; 2, denoising processing is carried out on the core gray level image of the oil sand; and step 3, carrying out binarization processing on the denoised rock core grayscale image to obtain a binary image of oil sand. And 4, vectorizing the binary image of the oil sand to obtain a vector diagram of the oil sand. And 5, calculating the porosity and the effective porosity of the oil sand by using COMSOL software. And 6, carrying out a two-dimensional digital rock core seepage simulation experiment by using the COMSOL. The relationship between the oil sand porosity and the rock seepage characteristics is established, and the seepage characteristics of the oil sand can be quickly predicted only by simply carrying out two-dimensional digital core simulation.

The present invention relates to the technical field of reservoir oil-bearing property evaluation methods, and is a method for evaluating the oil-bearing property of shale oil based on mud logging data. The method includes using low-cost rock pyrolysis chromatography mud logging data and rock mineral data to propose a calculation formula for evaluating the oil-bearing property of shale oil reservoirs, and then intersecting with the effective porosity of nuclear magnetic logging. According to the intersection diagram, an evaluation interval is divided to form an evaluation chart for the oil-bearing property of shale oil reservoirs. The evaluation result of the reservoir oil-bearing property is obtained by combining the oil-bearing property index LI value of the shale oil reservoir. The present invention provides a technical solution for obtaining the oil-bearing property of a reservoir without nuclear magnetic logging. When it is actually applied in the Jimusaer shale oil block of the Xinjiang Oilfield, the goodness of fit can reach more than 0.85, the accuracy of the calculated oil-bearing property parameters can meet the requirements of reservoir evaluation, and at the same time, the cost of obtaining the oil-bearing property parameters is significantly reduced, thus providing a new way for the evaluation of the oil-bearing property of shale oil reservoirs.

The present application relates to the technical field of unconventional oil and gas reservoir effectiveness logging interpretation and evaluation, in particular to a mudstone biogas reservoir effectiveness evaluation system, method, device and medium. The correlation between the sand content index and the shale content is used to establish a shale content calculation model for high shale formation, and the shale content is calculated. This method greatly improves the calculation accuracy of shale content and effectively solves the problems of reservoir leakage and other problems in the process of calculating shale content in the prior art. Then, the shale content is used to calculate the effective porosity, the shale content and the effective porosity are used to calculate the permeability, and the effective porosity and the permeability are used to evaluate the effectiveness of the mudstone biogas reservoir. The shale content and reservoir physical property parameters calculated by the above method have good consistency with core analysis data, can truly reflect the formation conditions, and the evaluation results are more accurate, providing a reliable basis for subsequent oil and gas exploitation. The problem of low accuracy of mudstone biogas reservoir judgment in the prior art is solved.

The invention relates to the technical field of unconventional oil and gas reservoir effectiveness well logging interpretation and evaluation, in particular to a mudstone biological gas reservoir effectiveness evaluation system, method, equipment and medium. And establishing a shale content calculation model of the high-shale stratum by utilizing the correlation between the sand content index and the shale content, and calculating the shale content. According to the method, the shale content calculation precision is greatly improved, and the problems of reservoir leakage and the like in the shale content calculation process in the prior art are effectively solved. And then, calculating the effective porosity by utilizing the shale content, calculating the permeability by utilizing the shale content and the effective porosity, and evaluating the effectiveness of the mudstone biogas reservoir by utilizing the effective porosity and the permeability. The shale content and the reservoir physical property parameters calculated by the method are well consistent with core analysis data, the stratum condition can be truly reflected, the evaluation result is more accurate, and a reliable basis is provided for subsequent oil and gas exploitation. The problem that in the prior art, the mud rock biological gas reservoir judgment accuracy is low is solved.

The invention provides a carbon-debris-containing clastic rock reservoir oil-water layer geophysical logging identification method. The carbon-debris-containing clastic rock reservoir oil-water layer geophysical logging identification method comprises the steps that 1, the percentage content of carbon debris in rock is obtained; step 2, obtaining the oil saturation in the rock and the effective porosity for removing the influence of the carbon chips; 3, calculating the theoretical resistivity R theory of the stratum by utilizing the porosity and the oil saturation; step 4, obtaining a resistivity correction chart of the formation containing the carbon chips; step 5, performing correction to obtain a resistivity curve R correction without carbon chips; and step 6, establishing an oil-gas-water layer identification chart by using the resistivity curve R correction and the porosity without the influence of the carbon chips. According to the geophysical logging identification method for the oil-water layer of the carbon-chip-containing clastic rock reservoir, the identification accuracy of the oil-water layer of the reservoir is obviously improved, a large number of invalid layer tests are screened out, a huge amount of funds and a large amount of time are saved, and the economic benefits of oil-gas exploration and development are improved.