262 results about "Source rock" patented technology

A grading evaluation method for high-maturity gas source rock based on hydrocarbon generation and expulsion simulation includes: establishing a change curve of hydrocarbon generation yield based on a hydrocarbon generation thermal simulation experiment; establishing a change curve of hydrocarbon expulsion of source rocks based on a principle of material balance; determining a classification boundary of source rocks based on the change curve of hydrocarbon generation yield and the change curve of hydrocarbon expulsion of source rocks; and obtaining a spatial distribution of different types of source rocks by combining logging interpretation according to the classification boundary of source rocks. In the method, the evaluation model and change curve of hydrocarbon generation yield, retained gas volume and hydrocarbon expulsion volume of source rock are established, and the classification standard of gas source rock at different maturity stages is determined by combining the change curve of hydrocarbon expulsion efficiency under different maturities.

Systems, methods, and apparatus for characterizing reservoirs are discussed. As an example, a method for characterizing a reservoir is discussed that includes determining a ki parameter, a αE parameter, and a αP parameter based at least in part on the at least four pairs of effective stress and permeability; and predicting a hydrocarbon production rate from reservoir represented by the sample rock based at least in part on the ki parameter, the αE parameter, and the αP parameter.

The invention belongs to the field of shale oil exploration evaluation, and discloses an LgR method logging source rock evaluation model fitting parameter prediction method and a shale type shale oil resource quantity calculation method and system. The prediction method comprises the following steps: screening mudstone data in a logging curve; determining a plurality of combinations of possible values of fitting parameters K, a and b, and calculating corresponding mudstone baseline parameters; aiming at different combinations of possible values of fitting parameters K, a and b and corresponding mudstone baseline parameters, according to the screened mudstone data, utilizing an LgR method well logging source rock evaluation model to respectively calculate and obtain organic matter abundance fitting values; and based on the organic matter abundance fitting value and the organic matter abundance measured value, evaluating a fitting effect, and screening out a parameter value combination with the optimal fitting effect as a predicted fitting parameter of the well with the organic matter abundance measured value in the work area. According to the method, all possible parameter value combinations can be comprehensively screened, the influence of subjective factors is eliminated, and undetermined parameters are objectively and accurately predicted.

The invention relates to the technical field of oil-gas exploration, in particular to a hydrocarbon generation potential evaluation method for marine hydrocarbon source rocks. On the basis of determining terrestrial source and sea source organic matter proportions of marine facies hydrocarbon source rocks in different sedimentary areas, marine facies hydrocarbon source rock thermal simulation experiments of different terrestrial source / sea source organic matter proportions are carried out, and gaseous hydrocarbon yields of the marine facies hydrocarbon source rocks of different terrestrial source / sea source organic matter proportions and isotope characteristics and activation energy of gaseous hydrocarbons of different maturity degrees are determined; according to generation, storage and cover layer parameters of a research area, selecting a suitable model and giving suitable parameter values, performing numerical simulation on hydrocarbon source rocks with different terrestrial / sea source organic matter proportions, and finally quantitatively determining hydrocarbon generation potential of hydrocarbon source rocks with different sedimentary areas and different terrestrial / sea source organic matter proportions in the research area by combining burial-thermal history evolution of the research area. And obtaining a hydrocarbon generation and expulsion period and a charging process, and determining a main reservoir forming period. Compared with the prior art, the hydrocarbon generation potential evaluation accuracy of the marine hydrocarbon source rock can be greatly improved.

Methods and systems are disclosed. The method may include obtaining a first plurality of hydrocarbon source rock samples from a first well and a second plurality of hydrocarbon source rock samples from a second well, each well penetrating a portion of a subterranean region. For each of the first and second plurality of samples obtaining a set of kinetic parameter values, including a discrete distribution of activation energy and a common frequency factor and determining a weighted average activation energy value from the distribution. The method may further include identifying a first chemostratigraphic segment of the first well and a second chemostratigraphic segment of the second well, each based on the weighted average activation values; determining a correlated stratigraphic unit and mapping organofacies based on the first the second chemostratigraphic segments; and predicting hydrocarbon generation, retention and expulsion and determining a drilling target within the correlated stratigraphic unit.

The mineralogical, chemical, magnetic, and physical properties of a rock can be used to determine the amount of hydrogen that was generated during rock alteration and the remaining amount of hydrogen generation potential. The methodologies evaluate the hydrogen generation potential of geological samples and identify natural hydrogen source rocks. The mineralogy, elemental composition, iron content and oxidation state, and other properties of a geological sample may be determined. From the determined mineralogy and other properties of the geological sample, the amount of hydrogen which the geological sample may have generated may be quantified. This method can determine the maturity of hydrogen source rocks, the potential volume of hydrogen that can be generated in other parts of a given geologic province with higher degrees of hydrogen source rock maturity, and quantify the potential remaining volume of hydrogen that can be still be generated via secondary enhanced hydrogen stimulation processes.

The invention discloses a well logging prediction method and device applied to source rock geochemical parameters. The well logging prediction method applied to the source rock geochemical parameters comprises the steps that rock debris data and well logging data are collected and obtained, the amplitude limit of corresponding lithologic well logging response is divided, and a lithologic recognition standard is established; performing single well depth homing on the organic carbon data, and adjusting the depth position of an organic carbon sampling point; selecting a logging curve sensitive to the content of the organic carbon according to the measured data of the content of the organic carbon, and establishing a calculation model of the corresponding lithology and the content of the organic carbon; establishing a pyrolysis hydrocarbon logging calculation model; and selecting a new drilling well for formula verification. According to the method, the logging curve response characteristics are utilized, corresponding standards are divided for corresponding lithology, and meanwhile, based on the established calculation model of the corresponding lithology and the organic carbon content and the pyrolytic hydrocarbon logging calculation model, the method can be simply and reliably used for geochemical parameter logging prediction of a production well which is not subjected to coring.

A system and method for determining a net source rock thickness is disclosed. The method includes obtaining at least one well log, a first and second plurality of core samples from a wellbore, and for each of the first plurality determining a relative abundance of inorganic materials, and for each of the second plurality a set of organic material data. The method further includes determining a validated total organic content and a measured source rock thickness based on the organic material data and relative abundance of inorganic materials and determining a data and a prediction portion of the wellbore, based on the second plurality sample locations. The method still further includes determining a cut-off value for each well log, predicting a source rock thickness from the cut-off values and the net source rock thickness from a sum of the predicted and the measured source rock thicknesses.

The invention provides a method and device for predicting the volume of hydrocarbon source rocks in a rift valley system low-exploration-degree basin, and relates to the technical field of oil and gas geology, and the method comprises the steps: selecting a basin with a high rift valley system exploration degree as a scale region according to the spatial-temporal evolution characteristics of the rift valley system and the exploration degree of the basin, and determining an optimal construction condition; analogy is carried out on the dynamic background, the extension mechanism, the fault activity normal form and the structure type of the to-be-predicted basin and the scale area depression to obtain a class ratio K1, and the analogy premise of the to-be-predicted basin and the scale area is determined; performing analogy on the maximum activity rate of the boundary fault of the to-be-predicted basin and the scale area and the maximum thickness of the hydrocarbon source rock stratum system to obtain class ratios K2 and K3; and obtaining an analogy value K according to a formula # imgabs0 #, and calculating the volume of the to-be-predicted basin hydrocarbon source rock through the analogy value K. According to the technical scheme, prediction of the volume of the hydrocarbon source rock in the low-exploration-degree basin of the rift valley system is achieved, and the exploration cost is reduced.

A method for evaluating geological hydrogen source rock in a region is provided. The method includes: collecting magnetic susceptibility data from a plurality of subsurface locations in the region; receiving geophysical survey data of the region, wherein the geophysical survey data comprises geophysical data collected from above ground; tying the magnetic susceptibility data of the plurality of subsurface locations to the geophysical survey data; generating a geologic map of igneous rock, metamorphic rock, or mafic mineral- or iron-rich sedimentary rock within the region based on the magnetic susceptibility data using a model; and determining, based on the geologic map, a target zone of the geological hydrogen source rock with a potential for hydrogen production or with the potential for hydrogen accumulation.

The invention relates to a method for identifying natural gas causes by using methane carbon and hydrogen isotopes, and belongs to the technical field of oil-gas exploration and development. The method comprises the following steps: (1) acquiring methane carbon and hydrogen isotope data of a natural gas sample in a target area; (2) respectively carrying out thermal simulation experiments on the oil-type gas hydrocarbon source rock sample and the coal-formed gas hydrocarbon source rock sample, determining methane carbon isotope characteristics of the oil-type gas and the coal-formed gas, and judging typical oil-type gas and coal-formed gas in the natural gas sample in the step (1) by combining geologic characteristics; and (3) performing methane carbon and hydrogen isotope clustering analysis on the typical oil-type gas and the coal-formed gas, establishing a methane carbon and hydrogen isotope identification chart of the oil-type gas and the coal-formed gas, and identifying the natural gas cause according to the identification chart. The judgment method is higher in accuracy, and a feasible way is provided for judgment of natural gas reservoir causes in a high heat evolution stage and in regions with complex causes.

The invention discloses a rapid comprehensive survey method and system for natural hydrogen resources, and the method comprises the steps: rapidly delineating a prospective area through remote sensing and geochemical measurement, fusing aviation gravity and magnetism, earthquake, time-frequency electromagnetism and ground geological survey multi-source data, finding out the characteristics of hydrogen source rock, a migration channel, a reservoir stratum and a cover stratum through the integrated evaluation of source-communication-storage-cover, and carrying out the comprehensive survey of the natural hydrogen resources. A target area is optimized through multi-information fusion, drilling verification is carried out, and efficient exploration of natural hydrogen resources is achieved. According to the method, the potential of the natural hydrogen resource can be rapidly and accurately evaluated.

Embodiments of the present disclosure provide systems and methods for hydrogen production. Systems and methods provided herein may include obtaining one or more hydrogen prospects, the one or more hydrogen prospects selected based on one or more parameters. Systems and methods provided herein may include constructing one or more fracture networks based on the one or more hydrogen prospects, the one or more fracture networks each having a source rock area value. Systems and methods provided herein may include, based on the source rock area value for each of the one or more hydrogen prospects, generating a source rock exposure value for each of the one or more prospects. Systems and methods provided herein may include outputting a production prediction based on the source rock exposure value for each of the one or more hydrogen prospects.

The invention relates to the technical field of petroleum geophysical exploration, and provides a reservoir forming period hydrocarbon source rock paleo-pressure quantitative prediction method and system, and the method comprises the steps: solving the stratum denudation thickness based on a mudstone compaction curve extrapolation method; obtaining the thickness of a terrain skeleton, constructing a binary function based on the stratum denudation thickness and the thickness of the terrain skeleton to analyze an approximate solution, and inverting the stratum paleo-burial depth for the logging paleo-burial depth; obtaining the total porosity of the hydrocarbon source rock according to the stratum paleo-burial depth; quantitatively predicting the single well paleo pressure of the hydrocarbon source rock according to the total porosity; the multi-well paleo pressure is obtained based on the single well paleo pressure, interpolation is performed according to the multi-well paleo pressure to obtain the plane paleo pressure, in this way, the accurate well logging compaction trend line is established, the accuracy and reliability of the prediction result are improved by considering the influence of the shear wave speed, and therefore the accuracy of predicting the paleo pressure of the hydrocarbon source rock in the reservoir forming period is improved.

The invention relates to a device and method for evaluating the oil saturation of rock based on a step-by-step centrifugal volumetric method, and the device comprises a centrifugal unit which comprises a rotating support and a centrifugal tray sleeving the rotating support; the measuring unit comprises a plurality of closed detachable centrifugal tubes, the plurality of centrifugal tubes are uniformly arranged in the circumferential direction of the centrifugal tray, a pressurizing chamber, a sample chamber and a collecting chamber are sequentially arranged in each centrifugal tube from top to bottom, and the pressurizing chamber and the sample chamber are separated through a sealing partition plate and are controlled to be opened and closed through a valve; and the sample chamber and the collection chamber are separated by a filter screen. Compared with an organic solvent, the supercritical CO2 adopted by the method has obvious advantages in the quantification of the crude oil of the source rock. The oil content measuring agent has both gas diffusivity and liquid solubility, is small in molecular size, can penetrate through tiny pores of source rocks, is higher in dissolving capacity for heavy components in crude oil, and can fully extract the crude oil in various pores and reduce residues, so that the oil content of the rocks is more accurately quantified.

The invention provides a method and a device for extracting soluble organic matters of a carbonate reservoir, and the method for extracting the soluble organic matters of the carbonate reservoir comprises the following steps: extracting a reservoir rock sample with a first mesh number to obtain free-state soluble organic matters and first residual substances of the reservoir rock sample; crushing the first residual substance to a second mesh number, and removing carbonate minerals in the first residual substance; extracting the first residual substance from which the carbonate minerals are removed so as to obtain bound-state soluble organic matters and second residual substances of the reservoir rock sample; crushing the second residual substance to a third mesh number to destroy reservoir rock particles of the reservoir rock sample; and extracting the second residual substance crushed to the third mesh number to obtain the inclusion soluble organic matter. According to the method, carbonate reservoir rocks with different granularities are extracted for multiple times to obtain soluble organic matters in different occurrence states, and the soluble organic matters are compared with hydrocarbon source rocks in characteristic to judge the oil and gas filling period.

The invention discloses a hydrocarbon source rock TOC content plane distribution prediction method based on a mud-to-ground ratio, and relates to the technical field of oil-gas exploration and development, and the method comprises the following steps: dividing a single well sequence and a sedimentary facies, and carrying out the statistics of the mud-to-ground ratio of a stratum between interfaces; according to the TOC test result and the logging curve of the hydrocarbon source rock sample, a single well TOC content prediction model is established, and the TOC average content of hydrocarbon source rocks between interfaces is counted; obtaining a mud-to-ground ratio plane contour map; establishing an organic matter sedimentary geologic model, and analyzing the correlation between the TOC average content and the mud-land ratio; establishing a quantitative characterization mathematical model between the mud-land ratio and the TOC average content, and matching the quantitative characterization mathematical model with an analysis result of the organic matter deposition geologic model; drawing a TOC plane contour map according to the mud-to-earth ratio plane contour map and the quantitative characterization mathematical model; according to the method, the distribution of the high-abundance hydrocarbon source rocks can be described more accurately, the reliability is high, and the result accuracy is high.

The embodiment of the invention discloses a stratum denudation data determination method and device, equipment and a medium. The method comprises the following steps: determining a target layer, a Shanghai generic surface and a Shanghai generic surface of which stratum denudation data needs to be calculated; wherein the upper marine flooding surface is located above the top surface of the target layer and closest to the top surface of the target layer, and the lower marine flooding surface is located below the bottom surface of the target layer and closest to the bottom surface of the target layer; determining denudation points according to the target layer and the underlying stratum; wherein the underlying stratum is a stratum located between the bottom surface of a target stratum and a lower sea flooding surface; and determining the stratum denudation amount according to the thickness between an upper line extending upwards in the stratum direction from the denudation point and the bottom surface of the target stratum. According to the scheme, the stratum denudation amount can be determined more accurately and quickly according to the stratum characteristics and the seismic data which are easy to obtain, higher practicability is achieved, and basic data are provided for later-stage structural analysis, hydrocarbon source rock evolution, oil and gas accumulation condition analysis and the like.

The application discloses a sparse well area hydrocarbon source rock TOC prediction method and system, an electronic device and a medium, relates to the technical field of hydrocarbon source rock carbon content prediction, and comprises the following steps: establishing a virtual well in a well-free area; determining the seismic attribute of the virtual well based on a seismic attribute extraction method; determining the lithology of the virtual well based on the seismic attribute of the virtual well and a sandstone and mudstone lithology prediction model, and extracting the mudstone section of the virtual well; determining the longitudinal continuous TOC prediction value of the hydrocarbon source rock in the mudstone section of the virtual well based on a single-well longitudinal continuous TOC prediction model; and combining the longitudinal continuous TOC prediction value and the measured TOC value of the hydrocarbon source rock in the mudstone section of the virtual well to construct a three-dimensional TOC attribute body of the target sparse well area based on a preset geological condition constraint, so as to predict the TOC of the hydrocarbon source rock in the target sparse well area. The application realizes higher-precision quantitative evaluation and prediction of the TOC of the hydrocarbon source rock in the sparse well area.

A method of deploying a pulsed neutron logging tool. The method may comprise detecting natural gamma rays from the subterranean formation via one or more detectors of the pulsed neutron logging tool, broadcasting neutrons into the subterranean formation, and detecting neutron-induced gamma rays and natural gamma rays from the subterranean formation. The method may further comprise creating an inelastic spectrum, a capture spectrum, or a capture time decay from the natural gamma rays or the neutron-induced gamma rays, forming an inelastic yields, a capture elemental yields, or a formation sigma form the inelastic spectrum, the capture spectrum, or the capture time decay, creating a closure model from the inelastic yields and / or capture elemental yields and / or a formation sigma, and identifying a porosity, a mineral weight fraction, or a quality figure of merit from the closure model that quantifies geologic hydrogen reservoir quality.

The invention relates to a generation method, device, equipment and medium of a natural gas cause identification chart, in particular to the technical field of natural gas exploration, and the generation method comprises the following steps: performing a hydrocarbon generation simulation test on a hydrocarbon source rock sample to obtain gaseous analysis gas; performing natural gas composition analysis, natural gas C6-C8 light hydrocarbon composition analysis and natural gas C1-C5 carbon isotope and hydrogen isotope analysis on gaseous analysis gas, and drawing a gas component-gas component relational graph, a light hydrocarbon component-light hydrocarbon component relational graph and a hydrocarbon gas carbon isotope-carbon isotope relational graph of different closed systems; and screening parameters with differences to establish a natural gas cause identification chart of the high-over mature multi-closed system. According to the generation method provided by the invention, a hydrocarbon generation simulation experiment and oil-gas product chemical analysis are carried out, a multi-closed system natural gas cause identification chart is established, and theoretical support is provided for cover layer closure evaluation in regional oil-gas exploration, regional oil-gas resource evaluation and oil-gas-containing distant view and exploration field evaluation.

The invention belongs to the technical field of geological research, and provides a helium source rock prediction method and device, a storage medium and equipment, and the method comprises the steps: taking a bed rock top surface seismic horizon explained and tracked by a target area as a bed rock top surface, and taking a preset time window below the bed rock top surface as a target object; making a bedrock seismic waveform classification attribute graph of a preset time window; according to the bedrock seismic waveform classification attribute graph and the seismic reflection characteristics of the various different types of rocks of the bedrock, determining the corresponding relation between the different types of rocks of the bedrock and different seismic waveform distribution areas displayed by the bedrock seismic waveform classification attribute graph; and predicting helium source rocks of different types based on the corresponding relationship and different seismic waveform distribution areas displayed by the bedrock seismic waveform classification attribute graph to obtain a prediction result. Through the prediction method, on the premise of not depending on gravity and magnetic data, the prediction accuracy of the helium source rock can be greatly improved.

The invention discloses an oil gas hydrocarbon generation pressurization charging wave and range characterization method based on energy conservation, and relates to the technical field of oil exploration and development. In order to solve the problem that a traditional method focuses on macroscopic reservoir formation qualitative description and lacks a filling degree accurate quantification method, energy of different sources is superposed to calculate total hydrocarbon expulsion kinetic energy of hydrocarbon expulsion of hydrocarbon source rocks; the energy from different sources comprises under-compaction kinetic energy, hydrocarbon generation volume expansion kinetic energy and fluid elasticity energy; quantizing the energy attenuation of the oil gas in the migration process from the hydrocarbon source rock to the reservoir; a charge distance limit is determined based on the total hydrocarbon expulsion kinetic energy and the energy attenuation of the migration process.

The invention discloses a three-dimensional space oil-gas migration path tracking method and device based on a geological structure trend, equipment and a medium. The three-dimensional space oil-gas migration path tracking method comprises the following steps: gridding three-dimensional geological horizon data to form a three-dimensional space grid; taking any point in the hydrocarbon source rock area on the three-dimensional space grid surface, calculating the total gradient between the point and the four grid lines of the grid where the point is located, and taking the intersection point of the grid lines which are intersected and have smaller total gradient in the same direction as the starting point of oil-gas migration tracking; picking up eight grid points adjacent to the starting point, respectively calculating vertical gradient components of the grid points and the starting point, determining a first oil-gas migration point, and so on to obtain n oil-gas migration points; setting boundary conditions, and stopping oil-gas migration when the oil-gas migration reaches the boundary conditions; and storing the space coordinates of all the tracked grid points as trend path data, and drawing a space route map of oil and gas flowing and transporting outwards from the hydrocarbon source rock. Therefore, the research efficiency and the exploration precision of the basin model can be effectively improved.

The invention discloses a method and system for predicting the maximum height of an oil column of an upper-generation lower-storage type sandstone reservoir, and the method comprises the steps: building a dynamic critical equilibrium relational expression which takes hydrocarbon expulsion intensity and oil column formation height as unknown quantities and is used for representing an oil column formation condition and a force equilibrium relation according to the basic parameters of a hydrocarbon source rock stratum to be researched; according to pyrolysis experiment parameter data of multiple wells in the hydrocarbon source rock stratum to be researched, hydrocarbon expulsion intensity at different depths is calculated; and substituting the hydrocarbon expulsion intensities at different depths into the dynamic critical equilibrium relational expression so as to obtain the maximum oil column formation height at different depths. According to the method, the reliability and the accuracy of predicting the maximum height of the oil column of the upper-growing lower-storage type sandstone reservoir are improved.

Methods for identifying, evaluating, and high-grading rocks associated with past or future potential generation of hydrogen from geologic materials are provided. For example, a method for evaluating a hydrogen system within a geological source rock includes obtaining a geological sample of the geological source rock; extracting 'mobile' gases of the geological sample under a pressure gradient; evaluating the 'mobile' gases extracted from the geological sample; and quantifying a volume of hydrogen previously generated based on the 'mobile' gases.

The invention discloses a method and equipment for determining the initial reservoir forming depth of shale oil, and the method comprises the steps: obtaining curves of oil-generating pressurization values of mudstone and carbonate rock along with time through an oil-generating pressurization experiment, then carrying out curve conversion, and calculating the initial reservoir forming depth of shale oil by calculating the capillary resistance of the carbonate rock. According to the method, the reservoir forming initial depth of the shale oil is determined according to the superposition curve and the capillary resistance, and due to the fact that the reservoir forming initial depth is determined through the superposition curve and the capillary resistance, the scheme does not need to emphasize on utilization of geological factors and is not affected by other factors, and the finally obtained result is more accurate. Moreover, the method provided by the invention considers the influence of mudstone and carbonate rock on the reservoir forming initial depth of shale oil at the same time, avoids the problem that only conventional oil and gas of single hydrocarbon source rock lithology are aimed in related technologies, and is suitable for determining the reservoir forming initial depth of unconventional oil and gas such as shale oil and the like.

The invention relates to the technical field of hydrocarbon source rock testing devices, in particular to a device and method for testing the oil discharge efficiency of hydrocarbon source rocks of different qualities, and the device comprises a support, a central pipe is fixed at the center of the support, and a drilling cylinder capable of moving up and down relative to the central pipe and rotating simultaneously sleeves the central pipe. A driving device capable of driving the drilling barrel to slide up and down and rotate simultaneously is mounted on the bracket; and an oil discharge hole communicated internally and externally is formed in the upper end of the central pipe. The device is reasonable and compact in structure and convenient to use, can be used for testing in an actual geological environment of the hydrocarbon source rock without collecting and treating a sample, can be used for directly testing the hydrocarbon source rock, does not need to bring the sample back to a laboratory for further analysis, reduces destructive operation of the sample, and improves the test efficiency. And the property of the underground hydrocarbon source rock can be known more accurately.

The present application relates to a kind of based on the evaluation method of in-situ enrichment capacity of oil and gas in fracture source rock control, belong to the field of oil and gas exploration geology, including: selecting key fracture parameter as evaluation factor, key fracture parameter includes four types such as fracture structural style, fracture density, vertical fault throw and drilling-fracture nearest distance;Quantitative scoring model of each key fracture parameter is constructed, and fracture structural style score, fracture density score, vertical fault throw score and drilling-fracture nearest distance score are obtained;Fracture reservoir-controlling index is calculated;Based on fracture reservoir-controlling index, reservoir-controlling capacity is classified.The present application builds complete fracture structural parameter system, establishes the quantitative scoring model of each parameter, and builds fracture reservoir-controlling index using weight assignment method, realizes the quantitative evaluation of fracture reservoir-controlling capacity, standardization and comparability.

The invention belongs to the technical field of oil-gas exploration and development, and discloses a method for predicting the quantity of oil resources in a thin-well low-exploration basin, which comprises the following steps of: 1, determining a hydrocarbon generation threshold depth and a hydrocarbon generation period of a hydrocarbon source rock stratum section; and 2, recovering the paleostructure of the hydrocarbon generation period, and delineating the area of the mature hydrocarbon source rock on a plane distribution diagram of the paleostructure. And 3, determining a dark mudstone distribution range to obtain an effective hydrocarbon source rock area. And 4, calculating the percentage content of the mudstone. And 5, according to the mudstone percentage content, constructing a mudstone thickness model of the hydrocarbon source rock stratum section. And 6, dividing the mudstone thickness model of the hydrocarbon source rock stratum section in the effective hydrocarbon source rock area into a plurality of units, and calculating the average thickness of each unit. And 7, calculating the petroleum resource quantity of each unit, and accumulating to obtain the basin petroleum resource quantity. Accurate area data and thickness data are provided for predicting the petroleum resource quantity, and the efficiency and accuracy of predicting the petroleum resource quantity are improved through division unit calculation.