42 results about "Effective porosity" patented technology

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 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 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 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 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 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 invention provides a shale oil reservoir quality classification method, equipment, a medium and a product, and relates to the technical field of petroleum logging. The method comprises the following steps: determining effective porosity and pore structure parameters of the shale oil reservoir according to logging information of the shale oil reservoir; according to the effective porosity, the effective thickness of the shale oil reservoir dessert section is determined; determining quality parameters of the shale oil reservoir according to the effective porosity, the pore structure parameters and the effective thickness of the dessert section; and determining the quality category of the shale oil reservoir according to the quality parameters. According to the method provided by the invention, the shale oil reservoir can be accurately subjected to quality classification and evaluation according to the pore structure characteristics.

The invention relates to an improved saturation model construction method based on variable rock electrical parameters, and belongs to the technical field of geological exploration. The method comprises the following specific steps: determining formation water resistivity; determining values a, b, m and n of the research area; establishing a relationship between the cementation index m and different types of porosity; establishing a relation between the conductive porosity and the effective porosity; establishing an improved cementation index m model, wherein a = 1; and calculating the saturation of the reservoir. The method aims at solving the problems that in the prior art, the cementation index m change range is too large, and saturation calculation is not accurate.

The invention discloses a deep compact sandstone gas reservoir identification method and device, a medium and equipment. The method comprises the following steps: sampling a rock core to obtain a plurality of rock core samples; obtaining the effective porosity of the plurality of rock core samples, the longitudinal wave velocity saturated with different fluids and the rock sample density saturated with different fluids through a plurality of groups of experiments; constructing an effective porosity-fluid impedance cross plot and analyzing the effective porosity-fluid impedance cross plot; constructing a rock physical volume model of the deep compact sandstone reservoir; constructing a rock longitudinal wave velocity and density relational expression under the condition of complete water saturation and constructing a rock longitudinal wave velocity and density relational expression under the condition of complete natural gas saturation; and constructing a fluid impedance ratio model to judge the fluid property of the deep compact sandstone reservoir. According to the method, the impedance ratio model formula of stratum saturated water and saturated fluid is obtained through the fluid impedance ratio model, so that the influence of oil-based mud invasion and underlying pressure on sandstone reservoir judgment is eliminated, the recognition result is accurate and reliable, and the precision is higher.

A method for determining the porosity of shale oil samples with effective pore space. This method primarily addresses the problem of inaccurate determination of effective storage space porosity caused by fractures resulting from poor oil and gas extraction in oil-bearing shale and loss of clay water. The method is characterized by the following steps: S1, preparing a shale sample; S2, immersing the sample in a saturated solution for self-saturation and recording the self-saturation time; S3, measuring the mass of the sample in the saturated solution using a hanging scale and the wet sample mass filled with saturated solution, determining the density of the saturated solution, and calculating the total sample volume; S4, removing oil, ventilating, and dehumidifying the sample; S5, measuring the dry sample mass and sample skeleton volume, and measuring the mass of particles and dust inside the sample bag; S6, calculating the porosity of the shale sample. This method eliminates the influence of fractures caused by sample dehydration, accurately determines the effective porosity of shale oil samples by retaining clay-adsorbed water in situ while removing pore water, and features a short experimental cycle and high accuracy.

The application provides a quantitative analysis method for ore pore and fissure structure, and relates to the technical fields of mineral processing, metallurgical engineering and geological analysis. The method realizes accurate prediction of effective porosity of heap leaching ore by coupling on-site particle size investigation, laboratory "quasi on-site" heap construction, ore block fissure microscopic measurement and mass-volume conservation calculation. The method effectively overcomes the technical problems that the traditional method depends on single scale measurement, and is difficult to comprehensively reflect the complex structure from nanoscale pore to centimeter scale fissure, especially for the mixed ore of coarse and fine particle grades. The existing technology often processes different particle grades respectively, lacks systematic integration and mutual correction, and causes deviation of the calculation results of porosity and fissure rate.

The invention provides a quantitative analysis method for pore and fracture structures of ores, and relates to the technical field of mineral processing, metallurgical engineering and geological analysis. According to the method, accurate prediction of the effective porosity of the dump leaching ore is achieved by coupling on-site particle size investigation, laboratory'quasi-on-site 'pile body construction, ore block fracture microscopic measurement and mass-volume conservation calculation. The method effectively overcomes the defects that traditional methods mostly depend on single-scale measurement, complex structures from nano-scale pores to centimeter-scale cracks are difficult to comprehensively reflect, especially for ores with mixed coarse and fine particle fractions, different particle fractions are often treated in the prior art, system integration and mutual correction are lacked, and the measurement accuracy is poor. And the calculation results of the porosity and the fracture rate are deviated.

The invention relates to the technical field of oilfield development, in particular to a far-source low-permeability sandstone reservoir low-resistivity oil layer identification method, which comprises the following steps of: adding secondary resistivity correction value to resistivity logging data after primary correction, and solving resistivity logging data after secondary correction; calculating an apparent resistivity increasing coefficient of the production well by using the resistivity logging data after secondary correction; establishing an intersection chart taking the Y axis as the apparent resistivity increasing coefficient, the X axis as the effective porosity and the projection point as the oil testing result for the tested oil well in the area; according to the intersection chart established in the sixth step, the relation among the oil layer, the same oil-water layer, the water layer and the apparent resistance increasing rate is solved, the apparent resistance increasing rate of the well to be measured is substituted for comparison, and the oil testing result is predicted. The method is simple, efficient and high in practicability, oil reservoir oil and water layer development characteristics can be rapidly and qualitatively recognized, the oil and water layer space distribution relation can be depicted, the effective rate of measure well selection can be effectively improved, and oil reservoir evaluation work development can be guided.

The application belongs to the technical field of CO2 flooding, and discloses a method for testing low-permeability sandstone core saturation for CO2 flooding, which comprises the following steps: selecting a rock sample; treating the rock sample; measuring the effective porosity and density of the rock sample; selecting divinylbenzene and styrene as a carrier; using phthalate as a stationary phase, coating the stationary phase on the surface of the carrier to prepare a special saturation analysis chromatographic column, and selecting a chromatographic column with an inner diameter of 4 mm and a length of 2.2 m made of stainless steel; using an organic solvent cleaning method + a hot cleaning method to treat and maintain the contaminated detector; and using a combination of a standard curve method and a normalization method to calculate the instantaneous peak area and the total peak area. After the application of the new method, the measurement accuracy is higher, the various deviation calculations and mathematical statistics values are smaller, the relative standard deviation of the new method is less than or equal to 2.5%, the recovery rate is more than 97.5%, the technical quality and the measurement accuracy are doubled, the dosage of the medicament and the emission of toxic substances are reduced, and the work efficiency and the analysis efficiency are improved.

The invention provides a gravel content-based glutenite effective porosity calculation method, and belongs to the technical field of oil and gas field development engineering.The method comprises the following steps of obtaining glutenite slice identification data, rock core data and formation testing result data of a target interval, determining the reservoir pore space type and development condition through rock core and slice observation, and calculating the effective porosity of glutenite according to the reservoir pore space type and development condition; acquiring porosity and permeability intersection results corresponding to different gravel contents of the target interval; reservoir parameters of the target interval are analyzed, and factors influencing conglomerate reservoir development are subjected to influence evaluation; sorting the factors influencing the development of the conglomerate reservoir according to the influence, and selecting the factors in preset sorting as the calculation basis of the porosity; and establishing an effective porosity calculation equation. The correlation between the effective porosity calculated according to the method and the permeability is good, and the effective porosity of the glutenite reservoir can be accurately identified, so that the physical property characteristics of the effective reservoir are accurately identified, and the method can be used for new well reservoir evaluation.

This invention discloses a method and related equipment for evaluating effective porosity and heavy oil saturation. The method calculates multiple porosity components from collected echo measurements, then uses a dynamic logarithmic spectral composition method combined with porosity component inversion to retrieve the T2 spectrum. Finally, MRIL-P or MRT is used to interpret the retrieved T2 spectrum to obtain the effective porosity. Based on the analysis of the MRIL-P or MRT spectral interpretation principle, this method generates the T2 spectrum using a logarithmic spectral composition method. The logarithmic spectral composition method solves the problems of low accuracy and information loss of bound peaks before a certain time, thus accurately obtaining the effective porosity. Comparing the effective porosity calculated by the above method with helium porosity, the error is reduced to within 1.5%, significantly improving the porosity interpretation accuracy. This invention solves the technical problem that existing evaluation methods cannot accurately calculate the effective porosity of areas with "three low" characteristics (low porosity, low energy consumption, and low saturation).

This invention relates to the field of petroleum migration and accumulation mechanisms in tight reservoirs, and discloses a method, system, and computer program product for determining the lower limit of effective porosity in tight sandstone reservoirs. The method includes: determining the hydrocarbon expulsion intensity of the source rock using a preset hydrocarbon expulsion intensity determination model based on the values ​​of preset parameters; determining the gas charging force using a preset charging force determination model based on the values ​​of preset parameters and the hydrocarbon expulsion intensity; determining the critical pore throat radius for natural gas to exit the reservoir containing the source rock and enter the tight sandstone reservoir using a preset pore throat radius determination model based on the values ​​of various charging resistance parameters and preset parameters; determining the relationship between effective porosity and critical pore throat radius based on mercury intrusion porosimetry data of the tight sandstone reservoir; and then determining the lower limit of effective porosity of the tight sandstone reservoir based on this relationship. This method can effectively calculate the lower limit of porosity in tight sandstone reservoirs, providing a new approach for the evaluation of tight sandstone reservoirs.

The application discloses a device and method for measuring CO2 hydrate saturation in quartz sand system, which adopts fixed sample loading process, fills quartz sand in a high-pressure reaction kettle to form a columnar quartz sand medium sample, and arranges a temperature probe inside the sample; collects effective pore volume and effective porosity data; applies transient flat heat source step heating to the quartz sand medium sample to measure and obtain dry state equivalent thermal conductivity; after the quartz sand medium sample reaches a stable saturated state, saturated state equivalent thermal conductivity is measured and obtained; a CO2 supply system is used to introduce CO2 into the reaction kettle, and under the condition that CO2 hydrate stably exists, hydrate state equivalent thermal conductivity is measured and obtained; a corresponding relationship between CO2 hydrate saturation and thermal conductivity is established, and CO2 hydrate saturation is calculated.

This invention discloses a quantitative evaluation method for sweet spots in interbedded and interlayered shale oil formations, relating to the field of unconventional oil and gas exploration technology. The method obtains oil-bearing parameters, lithofacies structure parameters, pore and fracture parameters, and engineering parameters of the target formation. If the target formation is adjacent to a source rock with TOC > 1.5%, a vertical distance ≤ 3 meters, and OSI ≥ 100 mg / g, the number of times four conditions—interlayer frequency, interlayer thickness, effective porosity, and fracture porosity—are met is counted. If all four conditions are met and BI ≥ ​​45%, K... σ If the pressure is >2MPa, it is classified as a Class I sweet spot; if the quantity is ≥3, it is classified as a Class II sweet spot; if the OSI is ≥100mg / g but the target layer is adjacent to a source rock with TOC >1.5% and the vertical distance is ≤3 meters, it is classified as a Class III sweet spot. This invention achieves quantitative definition of key parameters and progressive screening of sweet spot segments, making the evaluation results highly consistent with actual production.

The embodiment of the invention provides a shale reservoir nuclear magnetic variation cut-off value porosity solving method based on multiple parameters. The technical problem that the porosity accuracy of density logging calculation is poor can be solved. The method comprises the steps of obtaining a first cut-off value based on attribute parameters of a shale reservoir to be measured; obtaining a first effective porosity according to the first cut-off value; based on the first effective porosity and the core porosity, a correlation result is obtained through root mean square error analysis; determining a second cut-off value meeting a first preset condition based on the correlation result; based on the second cut-off value and the logging parameters, an effective porosity cut-off value is obtained through a nuclear magnetic iteration method; and obtaining a second effective porosity based on the effective porosity cutoff value. The parameter regression minimum root mean square error nuclear magnetic well logging effective porosity cut-off value is utilized, the nuclear magnetic well logging effective porosity is calculated through the variable cut-off value, and the accuracy of the calculated porosity is improved.

The invention discloses a method for calculating a permeability coefficient of shield muck under the action of water and soil pressure. The method comprises the following steps: firstly, calculating the porosity of the shield muck under the action of different soil pressure; then considering the plugging effect of foam, and calculating the effective porosity of the shield muck under the effect of water and soil pressure; further, the effective particle size of the shield muck is combined, and the equivalent penetration pipe diameter of the shield muck under the action of water and soil pressure is calculated; and finally, on the basis of a Poiseuille formula and a Darcy law, constructing a shield muck permeability coefficient calculation formula under the action of water and soil pressure. According to the method, the influence of the water and soil pressure on the permeability coefficient of the shield muck can be fully considered, the permeability coefficient obtained through calculation is closer to the actual site situation, and a certain theoretical basis can be provided for shield gushing prevention and control.

The invention relates to the technical field of oil exploration, and provides a shale oil reservoir effective porosity determination method and device. The method comprises the following steps: acquiring target logging information to obtain the stratum density of a target stratum and the total organic carbon content of kerogen; judging whether the target logging information comprises element full-spectrum logging information or not; if yes, normalization analysis is carried out on the element full-spectrum logging information, and if not, combinatorial analysis is carried out on preset logging information in the target logging information, so that inorganic framework mineral component content information and clay content of the target stratum are obtained; calculating the density of the mixed inorganic mineral skeleton according to the mineral component content information of the inorganic skeleton; and calculating the effective porosity of the target stratum according to the stratum density, the total organic carbon content of kerogen, the mixed inorganic mineral skeleton density and the clay content. According to the embodiment of the invention, the influence of organic and inorganic mineral skeletons on the porosity can be considered, so that the calculation precision of the effective porosity of the shale oil reservoir is improved.

The invention discloses a karst disaster source water-rich characteristic multi-field coupling inversion analysis method. The method comprises the following steps: acquiring a tracing penetration curve and a water head change curve of a target area and extracting travel time characteristics; constructing a uniform parameter state vector containing a permeability coefficient, a water storage coefficient and an effective porosity, and establishing a forward model for describing solute transport and an underground water flow process; calculating a sensitivity matrix of the uniform parameter state vector to the observation data based on a forward model, and constructing a joint objective function containing a spatial adaptive regularization item according to the sensitivity matrix; and carrying out iterative solution on the target function by adopting a prediction-correction alternate updating strategy to obtain optimized parameter distribution and delineating a disaster-causing structure position. According to the method, by constructing a multi-physics field synchronous coupling mechanism and a self-adaptive constraint strategy, the problems of error one-way accumulation and physical parameter coupling splitting in traditional serial inversion are solved, and the recognition precision and resolution of the water-rich disaster-caused structure under the complex geological condition are improved.

The present application relates to the field of processing detection technology, especially to a geological environment risk prediction method and system based on multi-source heterogeneous data, the present application constructs a three-dimensional space attribute matrix containing effective porosity and organic carbon mass fraction and a groundwater flow velocity field; a three-dimensional space lag tensor matrix is constructed in combination with an organic carbon distribution coefficient; a step-by-step dynamic iterative reverse tracking of virtual particles is carried out to lock the leakage source, the constant resistance assumption of the whole field is broken, the mathematical decoupling of water flow driving and chemical interception is realized; through micro-grid level instantaneous dynamic speed reduction, the hidden danger of deducing too fast to pass the real source is eliminated, the locking of the historical hidden leakage position is realized, the confidence of the forward evolution prediction is improved, and solid data support is provided for the targeted management of environmental risks.

This invention relates to the field of experimental testing technology in oil and gas exploration and development, and particularly to a method for determining the effective porosity of shale oil samples based on two-dimensional nuclear magnetic resonance (NMR) technology. The method involves: preparing the target NMR sample using a freezing method, and calibrating the water and oil content values ​​separately; conducting water and oil distribution experiments on the sample, followed by pore characteristic experiments; calibrating the effective and ineffective pore regions and water and oil distribution regions of the sample's NMR signal, and providing different boundary delineation methods; calibrating the NMR signal obtained from the two-dimensional NMR, and delineating the effective and ineffective pore regions and oil and water distribution regions of the tested sample according to the boundary delineation methods; based on the shale pore properties, recovering the sample pore volume and performing two-dimensional NMR measurement to determine the total volume of the sample; obtaining data using oil-water data extraction methods, and combining this data with the total volume to obtain the effective porosity. The method provided by this invention is convenient, fast, has a short experimental cycle, and high production efficiency.

The application discloses a shale oil reservoir space characterization method, a chart construction method and a measurement method. The characterization method comprises the following steps: performing linear cutting treatment on a shale sample to obtain a regular-shaped plunger sample; performing helium injection measurement on the regular-shaped plunger sample to determine effective porosity of the shale sample; performing nuclear magnetic porosity measurement on the plunger sample to determine total porosity of the shale sample; and characterizing shale oil reservoir space of the shale sample based on the effective porosity and the total porosity of the shale sample. The method optimizes a pretreatment step by performing linear cutting treatment on the shale sample, avoids the influence of residual oil in the sample on a test process and a result on the premise of ensuring the accuracy of experimental results, and further establishes a comprehensive characterization mode of the shale oil reservoir space based on helium injection measurement and nuclear magnetic resonance measurement.

The application discloses a kind of complex structure area shale gas resource quantity calculation method and system, belong to shale gas field, steps include: S1. collection complex structure area three-dimensional seismic data, well logging data and core analysis data, and carry out high frequency denoising and wave impedance inversion;S2. fracture distribution model is generated using fracture structure quantitative description algorithm, and three-dimensional geological structure model is established in combination with well logging lithology identification;S3. three-dimensional geological structure model is corrected to high-precision stratum thickness, and reservoir effective stress distribution is calculated using stress field numerical inversion;S4. reservoir effective porosity-permeability parameter distribution is calculated in combination with porosity-permeability nonlinear coupling equation;S5. obtain porosity structure parameter, and superimposed formation reservoir physical property comprehensive model;S6. to the model is carried out super-resolution volume modeling, generates three-dimensional reserve model;S7. based on three-dimensional reserve model, cell resource quantity is calculated and summed up in unit. Advantageous effect: improve the accuracy and stability of complex structure area shale gas resource quantity calculation.