62 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 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 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 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 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 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 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 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 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.

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 a shale oil sample oil-water saturation determination method based on an ethanol extraction technology, and solves the problem that an existing method is difficult to realize shale oil sample oil-water saturation test capable of retaining clay adsorbed water in situ and removing and determining pore water, oil and porosity on a single sample. The method comprises the following steps: S1, preparing a shale sample; s2, determining an ethanol extraction time window; s3, extracting pore water of the shale sample to be detected according to the time determined by the extraction time window; s4, measuring the total volume of the shale sample to be measured; s5, removing oil and water in pores of the shale sample to be detected to obtain the mass of a dry sample; s6, measuring the pore water volume of the shale sample to be measured; s7, measuring the volume of the to-be-measured shale sample skeleton; and S8, calculating the oil-water saturation of the shale sample to be detected. According to the method, oil, water and effective porosity in pores of the shale sample can be removed and measured by adopting a single sample, and water adsorbed by clay can be retained at the original position.

The application discloses a method and device for evaluating remaining geological reserves in the middle and late stages of gas reservoir development, and belongs to the technical field of gas reservoir exploitation. The method comprises the following steps: dividing a region where a target gas reservoir is located into a plurality of grids, wherein the grids in a gas-bearing area are effective grids; obtaining original effective thickness, original effective porosity and original gas saturation of each effective grid; obtaining current formation pressure of each effective grid; calculating current natural gas volume coefficient of each effective grid according to the current formation pressure of each effective grid; inputting the original effective thickness, the original effective porosity, the original gas saturation and the current natural gas volume coefficient of each effective grid into a gas reservoir geological reserve calculation model to obtain remaining natural gas geological reserves of the target gas reservoir. The method can ensure the accuracy of the result and accelerate the speed of evaluating the remaining geological reserves in the middle and late stages of gas reservoir development.

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 discloses a saturated medium-coarse sand medium permeability coefficient correction method, and relates to the technical field of geotechnical engineering and hydraulic engineering, and the saturated medium-coarse sand medium permeability coefficient correction method comprises the following steps: obtaining microstructure parameters of a saturated medium-coarse sand medium through a nondestructive testing technology, the microstructure parameters at least comprising an effective porosity ne, a tortuosity gamma and a pore average diameter dp; the double-path permeability coefficient calibration algorithm comprises the following steps: calculating a permeability coefficient based on a correction formula of the effective porosity ne and the permeability coefficient K; and calculating the permeability coefficient based on theoretical models of the effective porosity ne, the tortuosity gamma and the average pore diameter dp. According to the invention, an empirical calculation model based on effective porosity and a theoretical calculation model fused with tortuosity are constructed to form a dual-path correction algorithm system, so that the calculation precision of the permeability coefficient and the reliability of the algorithm in related engineering scenes are effectively improved; and an innovative algorithm system is provided for medium-coarse sand medium permeability coefficient evaluation in the fields of geotechnical engineering, hydraulic engineering and the like.

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 present invention discloses a shale reservoir classification and evaluation method based on machine learning and optimal fractal attributes, which relates to the technical field of shale reservoir evaluation and comprises the following steps: calculating fractal attribute indicators of a T2 spectrum, obtaining new cluster labels, obtaining optimal fractal attribute values, obtaining final classification labels, applying the final classification basis to all optimal fractal attribute values ​​of a target well, and obtaining a new classification result; the present invention performs multifractal calculations on original T2 spectrum data obtained by nuclear magnetic resonance logging, combines effective porosity data obtained from sealed coring data of corresponding well sections as a basis, divides effective porosities of different degrees into categories, performs systematic machine learning training on the fractal attributes corresponding to each category, obtains a set of classification intervals of fractal attribute values ​​based mainly on the fractal attribute with the greatest influence, and applies the intervals to all fractal attribute values ​​of the target layer section, thereby accurately classifying and evaluating shale reservoirs.

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).