87 results about "Kerogen" patented technology

The invention discloses a deep coal rock in-situ gas content and adsorption / free gas proportion calculation method and device, and relates to the field of reservoir resource potential evaluation.The deep coal rock in-situ gas content and adsorption / free gas proportion calculation method comprises the steps that an isotope fractionation model coupled with a double-dispersion pore structure (matrix pores and kerogen pores) and a multi-gas transmission mechanism (viscous flow, Knudsen diffusion and surface diffusion) is constructed; the accumulated analytic gas quantity and the apparent isotope value of the produced gas obtained through solving are fitted with the actually measured accumulated analytic gas quantity and the apparent isotope value of the produced gas, and key parameters corresponding to the optimal fitting result are obtained; and determining the in-situ gas content, the in-situ adsorption gas proportion and the in-situ free gas proportion according to the productivity evaluation parameters at the initial moment corresponding to the optimal key parameters. According to the method, the in-situ gas content, the in-situ adsorbed gas proportion and the in-situ free gas proportion of the deep coal rock are calculated on the basis of an isotope fractionation model coupled with a double-dispersion pore structure and a multi-gas transmission mechanism, so that the gas resource content of the deep coal rock is predicted.

A method for separating liquid-like (T2e) from solid-like (T2G) 1H NMR transverse relaxation times in porous media uses novel pulse sequences together with a 1H NMR spectrometer optimized for geological core samples. The method is applied to obtain 1D T2 distributions and 2D T1-T2 maps in organic-rich chalks for quantification of liquid-like signal (micropore fluids, meso-macropore fluids, fluids dissolved in organic matter, and clay-bound water) and solid-like signal (kerogen, bitumen, and clay hydroxyls). The novel pulse sequences comprise a solid-echo, which detects more solid-like signal than an FID. The method is used for fluid typing in micro / meso-macro pores, clay mineral identification, determination of kerogen content, and quantification of solvent-extracted bitumen versus bitumen expelled from kerogen due to swelling from dissolved hydrocarbons. The method is used to quantify the asphaltene, resin, aromatic, and / or saturate content of bitumen in the rock.

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 provides a method for identifying natural gas causes of a high-sulfur-content gas reservoir and application. The method comprises the following steps: S1, measuring carbon and hydrogen isotope and component data of high-sulfur-content natural gas of a research target layer and data of potential hydrocarbon source rock kerogen isotope and vitrinite reflectivity; s2, carrying out a natural gas sulfate thermochemical reduction reaction simulation experiment, and determining influence factors of the sulfate thermochemical reduction reaction on carbon and hydrogen isotopes and components of natural gas isotopes; s3, carrying out a potential hydrocarbon source rock hydrocarbon generation simulation experiment, and determining the influence of the hydrocarbon source rock thermal maturity on natural gas carbon and hydrogen isotopes and natural gas components; s4, selecting methane carbon and hydrogen isotopes of the natural gas as identification parameters according to the result, and establishing an identification chart of the gas source cause of the high-sulfur-content natural gas; and S5, substituting the measured carbon and hydrogen isotope values of the high-sulfur-content natural gas into the high-sulfur-content natural gas source cause judgment chart, and determining the cause and thermal evolution maturity of the high-sulfur-content natural gas sample.

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 an organic matter-rich rock physical modeling method and system considering multiple pore media, and the method comprises the steps: setting initial bulk moduli and shear moduli of different minerals, and obtaining the bulk modulus and shear modulus of a rock skeleton; obtaining a predicted organic carbon content based on a logging curve; the kerogen content is obtained by predicting the organic carbon content; the porosity of communicating holes in a rock skeleton is corrected through the content of kerogen; adding kerogen as a solid filler into the rock skeleton; different pore types are distinguished, and pores are added into the rock skeleton; bound water is added into the rock skeleton; adding a movable fluid into the rock skeleton; determining the bulk modulus and shear modulus of minerals in the rock skeleton; and the longitudinal and transverse wave speed prediction effect is optimized. Organic carbon is converted into kerogen, the kerogen is added into a rock skeleton to correct the content of dry communicating holes and bound water pores, and fluid is added by considering different pore conditions, so that the accuracy and reliability of a model speed prediction result are improved.

A method of treating kerogen is provided. The method includes: generating a fracture network in a subterranean formation including kerogen by injecting a treatment fluid through a wellbore into the subterranean formation, the treatment fluid including water, an oxidant, and nanoparticles, the treatment fluid oxidizing a portion of the kerogen in the subterranean formation while generating the fracture network; and injecting carbon dioxide (CO2) through the wellbore into the subterranean formation, the CO2 penetrating the subterranean formation through the facture network.

The invention discloses a natural gas-assisted oil shale self-heat-generation in-situ conversion development method, and belongs to the field of oil shale in-situ exploiting.The method comprises the steps that an inverse seven-point well pattern is arranged in a natural gas-assisted oil shale self-heat-generation in-situ conversion development target area to serve as a development well pattern, reservoir transformation is conducted on a reservoir of the target area, and a fracture network is formed; high-temperature nitrogen is injected through the injection well to locally preheat the oil shale reservoir, then normal-temperature air is injected into the injection well to cool the bottom of the injection well, and finally the normal-temperature air and natural gas are separately injected into the bottom of the injection well through the double-layer oil pipe. Under the assistance of natural gas, residues generated after kerogen thermal cracking are subjected to an oxidation reaction to release heat, an oil shale reservoir is heated, meanwhile, natural gas oxidation can effectively supplement insufficient heat release of low-oil-content oil shale ground storage residues in oxidation, successful triggering and operation of a self-heat-generation reaction are guaranteed, and the oil shale reservoir is protected from being damaged. And efficient output of oil-gas cracking products of the oil shale reservoir is realized.

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 invention discloses a shale anisotropic rock physical modeling method, electronic equipment and a medium. The method comprises the following steps: calculating an elastic anisotropy matrix Ccl0 of illite and montmorillonite mineral particles, namely an elastic modulus Ccl of VTI anisotropy of a clay mixture; the elastic modulus Cncl of the non-clay minerals is calculated; calculating the VTI anisotropy C1 of the solid matrix composed of the clay mineral and the non-clay mineral; calculating an elastic matrix Ck of the porous kerogen by using a Krief formula; based on the elastic matrixes C1 and Ck, calculating an elastic matrix C2 of a VTI matrix 2 by using an anisotropic equivalent constant theory; and based on the elastic matrix C2 and the inorganic aperture system stiffness matrix Cf, calculating a marine permian system shale elastic matrix Csat. The method provides a research basis for reservoir key physical property and anisotropy parameter analysis and reservoir mechanical property and oiliness evaluation.

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.

The invention discloses an organic matter-rich shale in-situ exploitation electric heating well pattern unit optimization method and device. The method comprises the steps that according to a designed heating well pattern unit, an experimental heating well pattern unit is obtained through equal-proportion reduction; obtaining an experimental data set obtained by performing a thermal simulation experiment by utilizing the shale sample; based on the experimental data set, the corresponding relation among the horizontal heating well spacing, the formation temperature and the actual heating time is established, and the ratio of the horizontal heating well spacing to the vertical heating layer spacing is determined according to different temperatures with the same distance from a heat source in the horizontal direction and the vertical direction; according to the minimum kerogen conversion temperature and the optimal heating time of the shale, the optimal horizontal heating well spacing of the shale electric heating well pattern is determined through the corresponding relation; and according to the optimal horizontal heating well spacing, determining the optimal vertical heating layer spacing, and reserving the structure of the designed heating well pattern unit to obtain the optimal electric heating well pattern unit. By means of the method, reasonable optimization of the in-situ exploitation electric heating well pattern unit of the shale rich in organic matter can be achieved.

A method for producing hydrogen gas is disclosed. The method includes providing kerogen; providing hydrogen; introducing the kerogen and hydrogen into a reaction chamber wherein the reaction chamber is operated at an operating temperature between about 455° C. and 510° C.; and removing a gas stream comprising hydrogen.

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 identifying the deposition environment of crude oil parent material, and relates to the technical field of petroleum geological exploration. A method for identifying the deposition environment of crude oil parent material comprises the following steps: reference material processing: separating crude oils from different deposition environments, performing chromatography-mass spectrometry analysis and chromatography-isotope-mass spectrometry analysis on the separated products, and obtaining the Pr / Ph value and the fluorene 13 C isotope, establish identification plate; sample processing: separate the crude oil sample to be identified, perform chromatography-mass spectrometry analysis and chromatography-isotope-mass spectrometry analysis on the separated products, and obtain the Pr / Ph value and fluorene 13 C isotope; Sample identification: The Pr / Ph value of the crude oil to be identified and the 13 The C isotope is projected onto the identification plate for identification. The method of the present invention is less affected by secondary effects, improves the accuracy of crude oil parent material sedimentary environment analysis, and facilitates the comparison of oil sources in sedimentary basins and the study of oil and gas migration paths.

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.