320 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 discloses a multi-source digital rock image fusion method based on ensemble learning, and relates to the technical field of oil and gas resource geological exploration and development evaluation, and the method comprises the steps: S1, scanning and preprocessing a multi-source rock image; s2, generator optimization of the cyclic consistent generative adversarial network; s3, optimizing three types of weak discriminators; and S4, constructing a strong discriminator based on ensemble learning and reconstructing the multi-source digital rock. According to the method, multi-source digital rock image fusion is realized, the advantages of a large-scale image and a high-resolution image are effectively fused, the problem that a multi-scale three-dimensional pore structure cannot be reconstructed by using a single image scanning mode is solved, and compared with a traditional cyclic consistent generative adversarial network method, the method has the advantages that the method is simple and convenient to implement. The relative error of the constructed digital rock physical parameters is remarkably reduced, the accuracy of rock physical numerical simulation is improved, the method is easy to apply and popularize in different oil and gas fields, and a foundation is laid for fine evaluation of the oil and gas reservoir rock physical parameters.

The invention discloses a method for evaluating the hydrocarbon supply range of medium-deep layer hydrocarbon source rocks and a related device, and relates to the technical field of geological exploration and oil and gas development, and the method comprises the following steps: taking the accumulative hydrocarbon generation amount of the hydrocarbon source rocks corresponding to each geological period of a sub-stratum as the initial amount of oil and gas migration; according to an oil-gas migration principle and lithofacies characteristics and fault characteristics in the fault lithofacies diagram of each sub-stratum, simulating an oil-gas migration path and an oil-gas convergence amount of each sub-stratum by utilizing an oil-gas migration geologic model, and determining a hydrocarbon supply range of hydrocarbon source rocks based on the oil-gas migration path and the oil-gas convergence amount; dynamic evaluation of migration paths and convergence ranges of oil and gas on a tectonic plane in different geological periods is realized, so that distribution and potential of oil and gas resources of a middle-deep stratum are accurately evaluated.

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.

The invention provides a method and a device for determining the hydrocarbon generation intensity of high and over-mature marine hydrocarbon source rocks. The method comprises the following steps: acquiring an original logging curve of a layer section of a target development hydrocarbon source rock; obtaining organic carbon contents of hydrocarbon source rocks at different depths, and generating an organic carbon content curve of the hydrocarbon source rocks; performing multiple regression analysis on the obtained original logging curve and the hydrocarbon source rock organic carbon content curve, and selecting a target logging curve; establishing a hydrocarbon source rock organic carbon content fitting formula; constructing a hydrocarbon source rock hydrocarbon generation amount fitting formula; and obtaining a calculation formula of the hydrocarbon generation intensity of the highly over-mature marine hydrocarbon source rocks by utilizing a hydrocarbon source rock organic carbon content fitting formula, a hydrocarbon source rock hydrocarbon generation amount fitting formula, a logging data interval and the hydrocarbon source rock densities corresponding to the hydrocarbon source rock samples with different depths. A large number of core samples do not need to be collected, and the core sampling and analysis testing cost is reduced; and the corrected calculation formula utilizes an accumulation method, so that man-made interference caused when the average number of the parameters is selected is avoided, and the operability is improved.

The invention discloses an effective hydrocarbon source rock development condition prediction method and a related device, and relates to the geophysical exploration and comprehensive technical field, the method comprises the following steps: capturing spatial feature processing sequence data through a total organic carbon content prediction model, training a strong complex mapping relation between the total organic carbon content and seismic attributes, and determining the effective hydrocarbon source rock development condition; meanwhile, a support vector machine classification model is utilized to analyze a mapping relation between seismic attributes and lithology data of a virtual well in a research area, intelligent prediction of the total organic carbon content and intelligent judgment and identification of lithology are completed respectively, the generalization ability of the model is improved, regional distribution of the total organic carbon content and the lithology can be predicted more effectively, and the prediction accuracy of the total organic carbon content and the lithology is improved. Therefore, high accuracy is kept in a complex geological environment. And finally, determining the thickness and position of the effective hydrocarbon source rock of the target layer section based on the lithology identification result and the total organic carbon content prediction result, thereby realizing accurate evaluation of the development condition of the effective hydrocarbon source rock.

The invention discloses a marine hydrocarbon source rock thickness plane distribution prediction method, device and equipment and a medium. The method comprises the following steps: acquiring a marine facies hydrocarbon source rock core of a to-be-researched area, and determining a logging curve corresponding to the marine facies hydrocarbon source rock core and a development interval range of the marine facies hydrocarbon source rock; and on the basis of the logging curve and the development interval of the marine hydrocarbon source rock, constructing a marine hydrocarbon source rock logging identification quantity version. And carrying out seismic inversion based on the marine facies hydrocarbon source rock logging identification quantity version to obtain a two-dimensional inversion seismic section, and determining the hydrocarbon source rock thickness of the marine facies hydrocarbon source rock based on the two-dimensional inversion seismic section. And through seismic horizon calibration, according to the hydrocarbon source rock thickness, determining predicted marine facies hydrocarbon source rock thickness plane distribution corresponding to the marine facies hydrocarbon source rock in the to-be-researched area, thereby making up the limitation of marine facies hydrocarbon source rock distribution prediction by singly using seismic data, and improving the accuracy of hydrocarbon source rock plane distribution prediction at the same time.

The invention relates to a method and a device for identifying hydrocarbon source rock types in a well area with less offshore sea-land transition facies. The identification method comprises the following steps: S1, acquiring required data; s2, according to the sporopollen phase analysis data, determining a hydrocarbon source rock division threshold value based on the sporopollen phase component content; s3, according to the hydrocarbon source rock division threshold value based on the sporopollen phase component content, determining the threshold value of the biogenic indication parameter of the biomarker compound corresponding to the hydrocarbon source rock and the condensate oil; s4, according to the threshold value of the biogenic indication parameter of the biomarker compound corresponding to the condensate oil, determining the threshold value of the natural gas light hydrocarbon parameter; and S5, drawing a cross plot according to the natural gas light hydrocarbon parameters, and dividing ranges corresponding to different types of hydrocarbon source rocks according to the threshold values of the natural gas light hydrocarbon parameters. According to the identification method and device provided by the invention, the identification accuracy of the hydrocarbon source rock type of the offshore sea-land transition facies sedimentary environment less-well area is remarkably improved, and the problem of limited samples in the less-well area is solved.

The invention relates to the technical field of rock compression simulation experiment devices, and provides an experiment device for simulating fracture development in a hydrocarbon source rock high-temperature pyrolysis process, which comprises: a box body, which is internally provided with a chamber for placing a hydrocarbon source rock; the heating module is arranged on at least one inner side wall of the box body and is used for heating the hydrocarbon source rock; the confining pressure loading module is arranged on at least one inner side wall of the box body and used for pressurizing the hydrocarbon source rocks, the confining pressure loading module is provided with a plurality of loading blocks which are adjacently arranged in the length direction of the inner side wall of the box body, and each loading block can apply pressure to the hydrocarbon source rocks at the corresponding position; and the detection module is arranged on the box body and is used for detecting crack development in the hydrocarbon source rock in the experiment process. The device can solve the problem that an existing experimental device cannot carry out multi-area pressure adjustment, different confining pressures can be applied to rocks with different depths by redesigning the confining pressure loading module, and then the actual geological environment is simulated.

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.

The invention relates to a method and a device for determining the organic carbon content of marsh hydrocarbon source rock, and the method comprises the following steps: obtaining the organic carbon content and a plurality of mineral component parameters of a series of rock cores of a sea-land transition phase hydrocarbon source rock stratum section, and determining the correlation between the organic carbon content and each mineral component parameter; screening at least one target mineral component parameter related to the organic carbon content based on the correlation; fitting to obtain a function relation between the organic carbon content and the core logging response value and at least one target mineral component parameter; determining at least one target mineral component parameter of the to-be-measured rock core based on the logging curve; and determining the organic carbon content according to the target logging response value of the to-be-measured rock core, the at least one target mineral component parameter and the function relation. The organic carbon content of the margarious hydrocarbon source rock calculated by the method has the characteristics of high accuracy and reliable result, and effective technical support is provided for logging evaluation of the organic carbon content of the margarious hydrocarbon source rock in exploration and development of shale oil and gas and compact oil and gas.

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 present invention discloses a method for determining the maximum burial temperature of a formation by using carbonate clumped isotopes. The method provided by the present invention comprises the following steps: collecting formation samples and petrological analysis; testing the carbonate clumped isotope Δ47 of the samples; calculating the clumped isotope temperature T of the samples Δ47 ; preliminarily estimating the range of the maximum burial temperature of the formation where the samples are located; and according to the preliminary estimation result, selecting a solid-state reset model to determine the maximum burial temperature of the formation. The present invention solves the problem that it is difficult to accurately determine the maximum burial temperature for ancient marine carbonate rock formations due to the lack of vitrinite or zircon, reduces the result error, clarifies the applicable scope of the method, improves the feasibility, and has very important significance for the evolution of the organic matter maturity of source rocks and the evaluation of oil and gas resources in this formation series.

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.

The invention relates to a method for evaluating the oil and gas transport capacity of a premature senility type oil source fault, and belongs to the technical field of oil and gas exploration, and the method comprises the following steps: determining a longitudinal cutting layer series of the fault according to an existing seismic data result, and judging whether the fault is the premature senility type oil source fault or not; calculating the fault displacement and the fault inclination angle of the premature senility type oil source fault according to the measured horizontal distance and vertical distance between the premature senility type oil source fault and the top surface of the hydrocarbon source rock stratum system and the included angle between the fault trend and the measuring line; according to the section depth, the fault dip angle and the stratum water density of the premature senility type oil source fault and the overlying stratum density of the premature senility type oil source fault, the section positive pressure of the premature senility type oil source fault is calculated; and according to the fault displacement of the premature senility type oil source fault, the fault inclination angle, the section positive pressure of the premature senility type oil source fault and the formation pressure coefficient, a conduction capability coefficient calculation model of the premature senility type oil source fault is established so as to quantitatively evaluate the oil and gas conduction capability of the premature senility type oil source fault.

The invention discloses a hydrocarbon source rock maturity determination method, device and equipment based on Raman spectrum. The method comprises the following steps: scanning a to-be-detected hydrocarbon source rock by adopting a Raman spectrum surface scanning method, and determining a plurality of scanning data, the Raman spectrum surface scanning method being used for analyzing the structural data of the to-be-detected hydrocarbon source rock; based on the plurality of scanning data, determining intensity values of a plurality of scanning points on the to-be-detected hydrocarbon source rock, and calculating a mean value of the plurality of scanning data, the intensity values being used for representing scanning results of the scanned points of the to-be-detected hydrocarbon source rock; based on the mean value, performing standardization processing on the intensity values of the plurality of scanning points, and determining a target spectrum; and determining the maturity of the hydrocarbon source rock to be detected based on the target spectrum. The technical problem that in the prior art, maturity evaluation has high requirements for the technical level of operators is solved.

The invention provides a hydrocarbon source rock-reservoir-engineering multi-parameter comprehensive prediction method based on a random forest, and relates to the field of geological exploration, the method comprises the following steps: collecting rock core experiment data, the rock core experiment data comprising free hydrocarbon content, movable porosity and brittleness index; logging information is obtained; constructing a data set through logging information and rock core experiment data; establishing a three-parameter prediction model based on a random forest algorithm; and through the trained three-parameter prediction model, completing three-parameter prediction from a single well to a research area and sweet spot identification in an oil and gas reservoir based on logging data. By improving a random forest algorithm, a three-parameter prediction model of various different input parameters and various different output parameters is established. Multi-parameter prediction from a single well to a research area is achieved, and whole-area dessert identification and evaluation are achieved according to a dessert classification evaluation table of the research area.

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 provides a method for recovering the maximum ancient ground temperature and regional thermal history of a marine facies or lacustrine facies sedimentary area. The method comprises the following steps: (1) selecting a carbonate sample, and carrying out effectiveness analysis on the carbonate sample to obtain a hydrocarbon source rock maturity test sample and a paleo-thermal history research sample; (2) performing pretreatment on the hydrocarbon source rock maturity test sample and the paleo-thermal history research sample obtained in the step (1), and then performing carbonate cluster isotope composition analysis and data validity selection to obtain test data; and (3) recovering the paleo-temperature and / or regional thermal history according to the available data obtained in the step (2). According to the method, the maturity (suffered maximum paleo temperature) of marine facies / lacustrine facies hydrocarbon source rocks is recovered by utilizing a cluster isotope method of carbonate of a hydrocarbon source rock interlayer or an adjacent layer, and a large set of well preserved carbonate samples is used for a regional paleo thermal history recovery technology, so that a basis is provided for realizing oil and gas resource evaluation and aggregation rule prediction; the method is greatly helpful for exploration of shale oil and gas and deep / ultra-deep oil and gas.

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.