72 results about "Kerogen" patented technology

The invention relates to the technical field of oil and gas geological exploration, in particular to an over-mature hydrocarbon source rock parent material type distinguishing method and system.The method comprises the following steps that regional deposition characteristics are studied, an over-mature hydrocarbon source rock deposition environment is recognized, principal elements and microelements are extracted in combination with a geological background, and component relevance is judged; and sorting representative sedimentary environment elements, and establishing a sedimentary environment associated element set. According to the method, accurate recognition of the sedimentary environment is achieved by extracting major elements and trace elements, representative elements are screened, proportional analysis is combined with the macerals, distribution characteristics of saprolite groups, exinite groups and the like are determined, the ratio relation between the macerals and inorganic elements is recognized, a ratio operation set is constructed, and the relation between the macerals and the elements is analyzed in a multi-dimensional mode. The relationship between parent material types and maceral characteristics is disclosed, a maceral type index model is constructed, hydrocarbon source rock parent material type division precision and sedimentary environment analysis systematicness are improved, and a scientific basis is provided for oil and gas resource exploration.

The invention relates to a method for decoupling organic matter primary-secondary cracking hydrocarbon generation conversion rate based on a gold tube hydrocarbon generation thermal simulation experiment. The method comprises the following steps: step 1, acquiring kerogen gold tube hydrocarbon generation thermal simulation experiment data; step 2, parametric modeling of the kerogen hydrocarbon generation process; step 3, constructing a least square target model under a multi-constraint condition; step 4, performing nonlinear least square optimization solution under the constraint condition; and 5, calculating the hydrocarbon generation conversion rate. According to the method, conversion rate calculation is carried out on the cumulant of each hydrocarbon generation process obtained through decoupling, the conversion rate evolution rule of the kerogen oil generation, gas generation, crude oil cracking gas generation, non-reactive carbon formation and other processes along with maturity change in the crude oil cracking process can be obtained, and a quantitative basis is provided for refined hydrocarbon generation evaluation.

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 a method for decoupling organic matter primary-secondary cracking hydrocarbon generation conversion rate based on gold tube hydrocarbon generation thermal simulation-solid product pyrolysis experiment. The method comprises the following steps: step 1, kerogen gold tube hydrocarbon generation simulation and solid product rock pyrolysis experiment data acquisition; step 2, parametric modeling of the kerogen hydrocarbon generation process; step 3, constructing a least square model of multi-source experimental information collaborative constraint; 4, carrying out optimization solution under a multi-source experiment information collaborative constraint condition; and 5, calculating the hydrocarbon generation conversion rate. According to the method, conversion rate evolution characteristics of each hydrocarbon generation process are quantitatively represented, conversion rate calculation is performed on cumulant of each hydrocarbon generation process obtained through decoupling, and conversion rate evolution rules of kerogen oil generation, kerogen gas generation, crude oil cracking gas generation, non-reactive carbon formation and other processes along with maturity changes in the crude oil cracking process can be obtained; and a quantitative basis is provided for refined hydrocarbon generation evaluation.

The invention discloses a method for identifying algae bombardment type oil shale based on carbon isotopes and biomarkers, and belongs to the field of testing or analyzing materials by means of measuring chemical or physical properties of the materials.The method comprises the steps that firstly, Soxhlet extraction is conducted on a cleaned, dried and smashed sample, and soluble organic matter and residual rock powder are obtained; separating the soluble organic matter family components to obtain saturated hydrocarbon and aromatic hydrocarbon components; then extracting residual rock powder kerogen, and analyzing carbon isotope; the method comprises the following steps: according to gas chromatography-mass spectrometry biomarker data of saturated hydrocarbon and aromatic hydrocarbon components, obtaining a 4-methylstane index, a ratio of C30 tetracyclic polyisoprene to C27 rearrangement stane and a ratio of phenanthrene series to naphthalene series; and finally, analyzing a parameter correlation relationship, dividing parameter boundaries where different lithologic sample plumbing areas are located, and establishing an algae bomb type oil shale quantitative identification standard based on the carbon isotope and the biomarker. According to the method, scientific, accurate and reliable identification of the algae bombardment type oil shale is realized.

The application relates to a method for decoupling primary-secondary cracking hydrocarbon generation conversion rates of organic matter based on a gold tube hydrocarbon generation thermal simulation-solid product pyrolysis experiment, which comprises the following steps: step 1, kerogen gold tube hydrocarbon generation simulation and solid product rock pyrolysis experiment data acquisition; step 2, parameterized modeling of the kerogen hydrocarbon generation process; step 3, construction of a least square model cooperatively constrained by multi-source experimental information; step 4, optimization solution under the cooperatively constrained condition of multi-source experimental information; and step 5, hydrocarbon generation conversion rate calculation. The application quantitatively characterizes the conversion rate evolution characteristics of each hydrocarbon generation process, and through conversion rate calculation on the cumulative amount of each hydrocarbon generation process obtained by decoupling, the conversion rate evolution law of the kerogen oil generation, gas generation and oil cracking process, the oil cracking gas formation and the unreactive carbon formation process with the change of the maturity can be obtained, and a quantitative basis for fine hydrocarbon generation evaluation is provided.

This invention discloses a method and apparatus for determining the total organic carbon content of kerogen based on oil saturation. The method includes: determining the total organic carbon content and oil saturation of a formation based on well logging data; determining the total organic carbon content of crude oil in the formation based on the oil saturation; and determining the total organic carbon content of kerogen in the formation based on the total organic carbon content of the formation and the total organic carbon content of crude oil in the formation. This method can accurately determine the organic carbon content of kerogen, thereby accurately describing the quality of source rocks.

The invention discloses a method for intensively developing a kerogen-rich shale oil reservoir by using a kerogen residual carbon resource, and relates to the technical field of unconventional oil and gas development. According to the method, water and oxygen-containing gas are injected into the shale oil reservoir rich in kerogen after electric heating in-situ exploitation, hydrogen and heat are generated by utilizing residual carbon enriched in the shale oil reservoir rich in kerogen, and kerogen at a large well spacing is further developed by utilizing the generated hydrogen and heat. According to the method, residual heat and residual carbon in the reservoir after in-situ development are electrically heated, the kerogen-rich shale oil reservoir after in-situ exploitation can be further developed without additional energy, the oil yield is increased, meanwhile, energy is saved, and the method is a novel green, low-carbon, safe and efficient unconventional oil reservoir development technology.

The invention discloses an organic matter identification method based on seismic wave dispersion, and relates to the technical field of petroleum geophysical exploration, and the method comprises the steps: obtaining a target pre-stack seismic trace set and matched logging data, building an underground medium initial model based on the kerogen content and elastic response characteristics in the logging data, and obtaining an underground medium initial model; a to-be-inverted parameter matrix and a reflection coefficient weight matrix of an incident angle are calculated through a Shaw reflection coefficient calculation equation, frequency-division seismic wavelets are generated through the high sensitivity of organic matter to transverse wave dispersion, and a positive operator is constructed in combination with the wavelets and the reflection weight matrix. A shear wave velocity dispersion gradient which is highly sensitive to organic matters and weak in response to pore fluid is used as a main control inversion parameter, a combined recognition constraint term is constructed by combining a longitudinal wave velocity dispersion gradient and attenuation spectrum morphological characteristics, and a spatial optimal solution of a forward operator and a seismic trace set is calculated through a minimization objective function. And quantitatively associating the spatial optimal solution with the geophysical response characteristics of the organic matters to generate an organic matter spatial distribution diagram of the target reservoir.

The present invention provides a method for predicting the production capacity of in-situ steam injection mining of oil shale, which belongs to the technical field of oil and gas field development. The method for predicting the production capacity of in-situ steam injection mining of oil shale uses the steam front evolution theory, combined with the basic characteristics of the pyrolysis reaction of kerogen in oil shale, to divide the entire oil shale reservoir during the steam injection in-situ mining process into different areas, establish a mathematical model for the in-situ steam injection mining of oil shale, and use it to predict its production capacity, while reflecting the different development stages of the oil shale reservoir; the production capacity prediction method belongs to the field of oil and gas field development, and can solve the problems of existing production capacity prediction methods such as numerous calculation parameters and poor calculation ability, which greatly increase the difficulty of solving the model and the model is prone to non-convergence, so that the production capacity settlement result cannot be given; at the same time, it can also solve the problems of existing methods such as difficulty in correcting the reaction model according to actual conditions, involving multiple experimental tests and theoretical calculations, and complex actual operations resulting in poor practicality.

The invention relates to the technical field of shale reservoir mechanical property evaluation, and provides a shale mechanical property determination method and device based on molecular simulation. The method comprises the following steps: constructing a first slit hole model of minerals of a target shale sample, a second slit hole model of kerogen organic matters and a third slit hole model between different minerals and / or kerogen organic matters; adding molecules of different fluids, and constructing a first slit hole model, a second slit hole model and a third slit hole model containing different fluids; and constructing a mechanical property model of the target shale sample according to the mineral combination of the target shale sample, the first crystal orientation, the characteristics of different fluids, and the first slit hole model, the second slit hole model and the third slit hole model containing different fluids. The method solves the problem that an existing method is difficult to accurately quantify the mechanical effect under the microcosmic nanoscale fluid characteristic-mineral component coupling effect.

The present invention provides a method for evaluating the composition and structure of ancient lake biomes, relating to the fields of paleoecology and oil and gas geology, and comprising the following steps: S1, obtaining two rock samples from lacustrine fine-grained sedimentary rocks; S2, performing kerogen separation and enrichment on one rock sample, and determining the major categories of ancient lake organisms under microscopic observation; S3, based on the major categories of organisms, performing gas chromatography, gas chromatography-mass spectrometry, and isotope mass spectrometry analysis on the other rock sample to identify the composition and content of biomarker compounds with biogenic significance and to identify the organism type; S4, based on the preservation efficiency of the identified biomarker compounds in the environment and the quantitative generation relationship between the biomarker compounds and their parent sources, restoring the original content of the compounds and determining the structure of the ancient lake biomes. The present invention has the following beneficial effects: accurate conclusions, high feasibility, and solves the problems of multi-source interpretation of the same type of biomarker compounds and restoration of the original content of the biomarkers.

The invention provides a manufacturing method of an identification slice under sporopollen phase fluorescence, and belongs to the field of microbody paleontology fossil analysis. The method comprises the following steps: dropwise adding an organic matter extracting solution rich in sporopollen fossil onto a glass slide, then adding glycerol into the organic matter extracting solution on the glass slide, and mixing to form a mixed solution; the periphery of the contour line of the cover glass is coated with ultraviolet curing glue, then the cover glass covers the predetermined area, coated with the mixed liquid, of the glass slide, so that the mixed liquid is limited in a sealed space defined by the glass slide, the cover glass and the peripheral ultraviolet curing glue, and a to-be-cured sheet is obtained; and carrying out ultraviolet irradiation on the to-be-cured sheet so as to cure the ultraviolet curing adhesive, thereby obtaining the identification sheet. The invention provides a novel manufacturing process of a sporopollen phase identification slice under fluorescence, not only can the identification work of sporopollen fossil be met, but also the analysis work of the sporopollen phase (kerogen maceral) under the fluorescence condition can be met.

The invention discloses a method and device for determining the full range of carbon content in rocks. The method comprises: S1, crushing the sample in a sealed vacuum, collecting gas at 100°C, and detecting hydrocarbon carbon FHC1 in kerogen and pores; S2, weighing a portion of the crushed sample in S1, collecting gas at 300°C, and detecting kerogen adsorbed hydrocarbons and pore hydrocarbon carbon FHC2; S3, crushing the remaining crushed sample in S2 in a sealed vacuum, weighing a portion of the crushed sample, pyrolyzing it at 850°C to detect organic carbon NTOC, and simultaneously oxidizing it at 850°C to detect total carbon C; S4, extracting the remaining crushed sample in S3 by supercritical carbon dioxide to detect kerogen heavy hydrocarbons and inclusion hydrocarbon carbon SIC; S5, quantitatively injecting hydrochloric acid into the remaining crushed sample in S4 under a sealed vacuum condition for dissolution, detecting carbonate mineral carbon CC by using a pressure increment value; detecting organic acid salt hydrocarbon carbon OAC by solution neutralization; S6, taking the remaining slag sample after hydrochloric acid dissolution in S5, pyrolyzing it at 850°C to detect kerogen hydrocarbon carbon KHC; and S7, calculating and outputting the results. This method has the advantages of low cost, simple operation and high detection efficiency.

The application provides a kind of low matured continental facies shale hydrocarbon generation process and pore structure relationship construction method, belongs to shale hydrocarbon generation process technical field.The application establishes low matured continental facies shale hydrocarbon generation process by using gold tube thermal simulation of kerogen sample under the same experimental conditions, and the mineral composition, pore structure and morphology characteristics are characterized by using gold tube thermal simulation of water adding plunger sample combined with scanning electron microscope, the corresponding relationship of low matured continental facies shale hydrocarbon generation process and pore evolution is obtained, so as to distinguish the advantage development temperature interval or maturity interval of shale oil and gas, and the reaction stage and pore structure evolution characteristics experienced are clear, which can provide new ideas for future hydrocarbon generation process reproduction, hydrocarbon generation mechanism discussion and resource dynamic evaluation of continental facies shale.Meanwhile, the gold tube thermal simulation of water adding plunger sample is used in the application, which can approximately simulate the real geological conditions, so that the experimental results are closer to the results under real geological conditions.

This invention relates to an evaluation method and system for hydrocarbon generation and pressurization in shale oil, belonging to the field of oil and gas geological evaluation and unconventional oil and gas accumulation simulation technology. The method includes: Step 1: Obtaining input parameters of the target shale layer; Step 2: Calculating the generated oil mass based on mass balance; Step 3: Establishing the first relationship between crude oil volume and overpressure; Step 4: Establishing the volume conservation relationship; Step 5: Establishing the relationship between formation water volume and kerogen volume and overpressure; Step 6: Simultaneously solving for hydrocarbon generation overpressure; Step 7: Introducing hydrocarbon expulsion feedback to correct the hydrocarbon generation overpressure calculation; Step 8: Calculating formation pressure, determining breakthrough hydrocarbon expulsion, and performing pressure release and state update; Step 9: Iteratively calculating multiple maturity nodes and outputting the episodic hydrocarbon expulsion evolution results. This invention quantitatively evaluates the overpressure accumulation process of shale layers during thermal evolution, improving the computability of shale oil accumulation dynamics analysis.

A method for operating a kerogen-rich unconventional gas reservoir characterized by there being multiple hydraulically-fractured wells drilled thereinto comprises: recovering a methane-containing gas from a first hydraulically-fractured well drilled into the gas reservoir, steam-methane reforming the recovered methane-containing gas to yield a hydrogen gas and an inorganic carbon-containing gas, injecting at least a portion of the hydrogen gas into a second hydraulically-fractured well drilled into the gas reservoir, and injecting at least a portion of the inorganic carbon-containing gas into a third hydraulically-fractured well drilled into the gas reservoir.

The application discloses a method for quantitatively analyzing mercury in different occurrence states in sedimentary rocks, belongs to the technical field of geological rock analysis, extracts kerogen from whole rock, respectively determines the mercury content and the organic carbon content of the whole rock and the kerogen, then carries out high-temperature thermal desorption analysis on equal quality of the two, obtains a thermal desorption curve, divides the release stages of different mercury occurrence states according to the thermal desorption curve, and calculates the content and proportion of mercury in each stage, and finally combines the total mercury content of the whole rock, the mercury content of the kerogen and the mass ratio, and obtains the inorganic mercury content through mass balance calculation. The method divides mercury into organic matter combined state (in kerogen) and inorganic combined state through physical separation and high-temperature pyrolysis, overcomes the multi-solution problem of traditional correlation fitting, significantly improves the accuracy and reliability of mercury as a volcanic activity tracer, and verifies the experimental data through mass balance calculation, avoiding the misjudgment of a single fitting method.

The present invention discloses a stepped modeling method for a multi-mineral shale molecular model with different water contents, including: obtaining shale mineral composition data and kerogen structure data of a research area; optimizing the shale mineral composition data to determine the types of minerals; constructing and optimizing mineral crystal models according to the types of minerals; constructing a kerogen planar model based on the kerogen structure data and performing geometric optimization to obtain a kerogen structure model; modeling the mineral crystal model and the kerogen structure model according to a preset mineral proportion to obtain a multi-mineral shale model without water content; calculating the number of water molecules required for models with different water contents by using the molar mass of the multi-mineral shale model without water content and the molar mass of water molecules; combining the determined number of water molecules with the multi-mineral shale model without water content to obtain multi-mineral shale models with different water contents; and performing structural optimization on the multi-mineral shale models with different water contents to obtain a final multi-mineral shale model with water content.

The application discloses a shale rock physical modeling method, device, equipment, storage medium and product, and relates to the technical field of seismic rock physical modeling. The method comprises the following steps: establishing an organic matter mineral mixture model containing clay and kerogen; establishing a brittle mineral mixture model; establishing a dry shale model containing pores according to the organic matter mineral mixture model, the brittle mineral mixture model and pore parameters; establishing a dry shale model containing pores and cracks according to the dry shale model containing pores and crack parameters; calculating the longitudinal wave velocity of a mixed fluid according to fluid characteristics, establishing an anisotropic fluid replacement model according to the flexibility matrix of the dry shale model containing pores and cracks and the longitudinal wave velocity; and establishing a shale rock physical model according to the dry shale model containing pores and cracks by using the anisotropic fluid replacement model. The anisotropy caused by the directional arrangement of clay and kerogen and cracks is comprehensively considered, and a more accurate rock physical model for a shale reservoir is established.

Methods for treating a kerogen-containing subterranean formation including providing a slickwater fluid comprising formate, present in a molality ranging from about 1.5 to about 15.0; and at least one oxidant; and, introducing the slickwater fluid into a subterranean formation comprising kerogen.

A method of enhanced gaseous hydrocarbons recovery is provided. The method includes placing at least two individual, independently-controllable heating elements aligned opposite one another and in the same location on a production tubing in a wellbore at a gaseous hydrocarbons-producing location of a geological formation to form a permanently-installed array of heating elements. The method also includes heating a portion of the geological formation containing a gaseous hydrocarbons deposit comprising kerogen with a gaseous hydrocarbons formation heating device comprising the permanently-installed array of heating elements, at a temperature sufficient to liberate gaseous hydrocarbons from the kerogen present in the gaseous hydrocarbons deposit and recovering the gaseous hydrocarbons by transporting the gaseous hydrocarbons via the production tubing to the surface. The gaseous hydrocarbons formation heating device comprises a controller configured to control the permanently-installed array of heating elements.

The invention discloses a method for calculating hydrocarbon-forming biological source composition of hydrocarbon source rock by using THM-GC-MS analysis technology and Bayesian reasoning, and relates to the technical field of hydrocarbon source rock research. The problems that a traditional hydrocarbon-forming biological research method is time-consuming, labor-consuming and incapable of accurately quantifying are solved. Comprising the following steps: step 1, extracting kerogen from rock by using an acid treatment method; step 2, drying the prepared kerogen, grinding and crushing, and uniformly mixing; step 3, calculating the content of fatty acid methyl ester by utilizing a THM-GC-MS analysis technology; and 4, selecting a modern biological fatty acid relative content database, inputting the modern biological fatty acid relative content database and the fatty acid methyl ester relative content obtained in the step 3 into a Bayesian reasoning program FASTAR, and outputting the hydrocarbon biological relative content. According to the method, the relative content of the hydrocarbon-forming biological source of the hydrocarbon source rock can be rapidly, simply and quantitatively calculated.

Disclosed herein is a method for identifying a high producibility zone in a shale reservoir. The method includes obtaining a total organic carbon (TOC) content and an organic sulfur content of a formation interval using geochemical measurements and determining a dielectric dispersion response of the formation interval using dielectric measurements. The dielectric dispersion response is processed to obtain an aperture system tortuosity parameter. The pore system tortuosity parameter correlates to a ratio of organic sulfur content to TOC content to identify the presence of a mature kerogen zone with high or low hydrocarbon producibility, an immature kerogen zone in which clay is present, and a non-producible or over-mature zone within a formation interval. The correlation is performed by comparing the ratio of organic sulfur content to TOC to an organic matter maturity threshold and comparing the pore system tortuosity parameter to a pore system tortuosity parameter threshold.

Methods for treating a kerogen-containing subterranean formation including providing a slickwater fluid comprising formate, present in a molality ranging from about 1.5 to about 15.0; and at least one oxidant; and, introducing the slickwater fluid into a subterranean formation comprising kerogen.

This invention proposes an inversion-assisted shale petrophysical modeling method that considers the complexity of clay-kerogen stratification and pore structure. Pores are divided into isolated microfractures (related only to clay and kerogen) and connected pores (developed in various minerals), and the proportion of connected pores is introduced to balance the influence of these two types of pores. A stratification index is introduced to describe the degree of particle orientation. A modeling process is established based on inclusion theory and the Brown-Korringa model. Three important auxiliary parameters, including the stratification index, the proportion of connected pores, and the aspect ratio of connected pores, are estimated by comparing the errors between predicted elastic parameters and actual well logging data in conjunction with the inversion. The inversion results are used to correct the established petrophysical model, making it more consistent with reality and improving the prediction accuracy of shale rock elasticity and anisotropy parameters. Well logging data testing verifies the effectiveness of this method.

The invention discloses a quantitative evaluation method for the influence of formation water in a shale reservoir on the methane adsorption amount. The quantitative evaluation method comprises the following steps: constructing a kerogen model of a target area; adding water molecules into the kerogen model to obtain a steady-state matrix model with a water molecule distribution conformation; inserting methane molecules into the steady-state matrix model to obtain the number of the inserted methane molecules at different temperatures and pressures; and determining a quantitative relationship between the methane gas suction amount and the underground fugacity and the moisture content by combining the number of the methane molecules, and completing quantitative evaluation of the influence of the formation water in the shale reservoir on the methane gas adsorption amount according to the quantitative relationship. The method disclosed by the invention reveals the occurrence state and aggregation characteristics of the methane gas in the water-containing shale reservoir, and has important guiding significance for further understanding the enrichment mechanism of the shale gas.

The invention relates to the technical field of coal-bearing basin resource exploration, and provides an acidic water sedimentary basin coal measure strata fine-grained rock lithofacies classification method. The method comprises the following steps: firstly, carrying out kerogen separation and organic element, TOC (Total Organic Carbon) and total rock analysis test on different rock core samples; the mass ratio Cd of the organic carbon in the organic elements is calculated, and then the total organic matter mass fraction is obtained; carrying out normalization treatment on four-end-member components including total organic matters, long quartz minerals, clay minerals and carbonate minerals; and finally, first-level and second-level lithology classification is performed according to the total organic matter content and the contents of the three types of components in sequence, and fine-grained rock facies classification is determined in combination with sedimentary structure analysis. The method for determining the conversion coefficient of the organic carbon and the organic matter is high in pertinence and more accurate; the lithofacies classification scheme fully considers the effect of organic matter components in lithofacies division of coal-series fine-grained rocks, is more suitable for coal-series fine-grained rocks with wide organic carbon content distribution, and can better reflect the advantages, disadvantages and differences of coal-series fine-grained rocks with different organic matter contents.

The invention discloses a method for determining the content of organic sulfur in hydrocarbon source rock, and belongs to the technical field of oil-gas exploration and development. According to the method, the organic sulfur content in the hydrocarbon source rock organic matter is calculated by adopting a method of combining total rock X-ray diffraction analysis and total sulfur analysis. The method comprises the following steps: firstly, obtaining an X-ray diffraction pattern based on a total rock X-ray diffraction test, carrying out phase analysis to obtain mineral composition in a hydrocarbon source rock powder sample, then quantitatively analyzing the mass percent of the sulfur-containing mineral in the hydrocarbon source rock powder sample according to a characteristic peak in the sulfur-containing mineral in the X-ray diffraction pattern, and further obtaining the inorganic sulfur content of the hydrocarbon source rock powder sample. Meanwhile, the total sulfur content of the hydrocarbon source rock powder sample is obtained through an element analysis experiment, and the difference value of the total sulfur content and the inorganic sulfur content in the sample serves as the organic sulfur content. According to the analysis method, kerogen does not need to be prepared, chemical reagents are not used in the whole process, the experiment process is shortened, operation is easy, safety and convenience are achieved, test data are stable and reliable, and repeatability is high.