30 results about "Kerogen" patented technology

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 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 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.

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.

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.

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.

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.

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.

The invention relates to the field of oil and gas field exploration and development, in particular to a shale oil hydrocarbon source rock quality logging evaluation method and device.The method comprises the steps that the total organic carbon content of kerogen of all points in a research area is determined according to the total organic carbon content of a stratum and the total organic carbon content of crude oil contained in the stratum; determining the effective point of the total organic carbon content of the kerogen from each point in the research area according to the lower limit value of the total organic carbon content of the kerogen contributing to reservoir formation; determining a hydrocarbon source rock development section in the research area layer by layer according to the depth of the effective point of the total organic carbon content of the kerogen; determining the effective thickness of a layer section corresponding to each effective point in each layer section in the hydrocarbon source rock development section; and evaluating the quality of the hydrocarbon source rock stratum section according to the effective thickness and the total organic carbon content of kerogen at the effective point. According to the scheme, on the basis of shale oil kerogen total organic carbon content evaluation and effective thickness statistics, a foundation is laid for analyzing a source-reservoir configuration relation and objectively evaluating shale oil resource potential and scale.

The invention discloses a method for analyzing the content of organic sulfur in hydrocarbon source rock based on a cracking technology, and belongs to the technical field of oil-gas exploration and development. The method comprises the following steps: carrying out thermal cracking on a dried hydrocarbon source rock powder sample by adopting an online flash thermal cracking gas chromatograph-mass spectrometer to obtain a cracking product of organic matters in the hydrocarbon source rock powder sample; carrying out chromatography-mass spectrometry test on the cracking product of the organic matter to obtain a chromatography-mass spectrogram; carrying out semi-quantitative analysis on the peak area of thiophene and homologues thereof and the peak area of toluene in the cracking product based on the chromatography-mass spectrogram to obtain the ratio of the content of thiophene and homologues thereof to the content of toluene; and calculating the organic sulfur content of the hydrocarbon source rock powder sample according to the ratio of the content of thiophene and homologues thereof to the content of toluene. According to the method, kerogen does not need to be prepared in the analysis process, use of precursor chemical reagents is avoided, the experiment process is reduced, operation is easy, safety and convenience are achieved, data are stable and reliable, and repeatability is high.

The application provides a kind of based on hydrocarbon generation kinetics of source rock original total organic carbon parameter recovery and evaluation method.The method realizes the recovery of residual oil amount by light and heavy hydrocarbon correction, and with the kinetic parameters such as dry kerogen hydrocarbon conversion rate, oil cracking conversion rate and coke generation proportion calibrated by thermal simulation experiment as the constraint, builds the evaluation model of intra-source cracking oil and its material balance formula, restores and evaluates the original S2, intra-source cracking oil amount, coke carbon content and original total organic carbon, and further reveals the mechanism of total organic carbon evolution of first decrease and then increase.This application provides a complete closed-loop framework from experimental calibration to geological parameter recovery, which significantly improves the geological reliability of hydrocarbon source rock resource evaluation.The method overcomes the limitations of traditional methods in the interpretation of total organic carbon evolution in high mature area, improves the accuracy of residual oil amount recovery, and provides a scientific, repeatable and reviewable technical path for hydrocarbon source rock resource evaluation.

The present application provides a kind of quantitative evaluation shale gas preservation condition method, comprising steps 1. Collecting gas sample to be evaluated area and carrying out natural gas component and isotope characteristic analysis.Step 2. Based on the kinetic Rayleigh fractionation model of carbon isotope in kerogen hydrocarbon generation process, the reaction process F of system is determined.Step 3. Determine the isotope fractionation factor ε.Step 4. The prediction of methane generation amount.Step 5. Quantitative characterization of natural gas dissipation efficiency.Step 6. Comprehensive evaluation of shale system preservation condition.The present application perfects the quantitative evaluation method of shale gas preservation condition, helps the comprehensive evaluation of shale preservation condition in complex tectonic deformation area of Sichuan Basin periphery, provides basis for the search of beneficial target area in shale gas exploration, and speeds up the exploration and development process of shale gas reservoir.

The present invention provides a method for decomposition of an oil shale kerogen into di- and tri-carboxylic acids, which is characterised in that the method is carried out in a flow reactor, into which the oil shale kerogen and a nitric acid are introduced, which forms a reaction mixture and which is heated in the flow reactor first at a temperature of 120-135 C and then at 140-165 C, resulting in a product mixture containing di- and tri-carboxylic acids and gases, which are discharged from the flow reactor.

This application relates to a method for decoupling the primary-secondary pyrolysis hydrocarbon generation conversion rate of organic matter based on a gold tube hydrocarbon generation thermal simulation experiment. The method includes the following steps: Step 1, acquiring thermal simulation data of kerogen gold tube hydrocarbon generation; Step 2, parametric modeling of the kerogen hydrocarbon generation process; Step 3, constructing a least-squares objective model under multiple constraints; Step 4, nonlinear least-squares optimization solution under constraints; and Step 5, calculating the hydrocarbon generation conversion rate. By calculating the conversion rate of the cumulative amounts of each decoupled hydrocarbon generation process, this invention can obtain the evolution law of conversion rate changes with maturity for processes such as kerogen oil generation, gas generation, and crude oil pyrolysis into gas and non-reactive carbon formation during crude oil pyrolysis, providing a quantitative basis for refined hydrocarbon generation evaluation.

The invention belongs to the technical field of oil and gas exploitation, and particularly relates to a shale oil adsorption state-free state targeted conversion method based on pore wall surface in-situ electrochemical modification. According to the method, a pulse electric field is utilized to drive a special targeting modification liquid to enter shale nano pores, an electrochemical polarization reaction is induced on the kerogen / mineral surface (pore wall surface), and the original oleophylic (Oil-wet) pore wall is forcibly modified into hydrophilic / aerophilic (Water / Gas-wet), so that the interfacial adsorption energy is greatly reduced, and the technical effects of stripping adsorbed oil and converting the adsorbed oil into flowable free oil are achieved. Compared with the prior art, the treatment efficiency is greatly improved, the chemical properties of kerogen / mineral wall surfaces can be permanently changed, and secondary adsorption of crude oil is avoided.

This invention discloses a method and apparatus for shale rock physical modeling. The method includes: determining a maturity index curve based on kerogen maturity correlation curves; determining the density, bulk modulus, and shear modulus curves of kerogen based on discrete data of kerogen modulus and the maturity index curve; determining the porosity curves of organic and inorganic matter based on the adsorbed gas and free gas content curves and the maturity index and density curves of kerogen; determining the dry rock density, P-wave and S-wave velocities, and shear modulus curves based on the density, bulk modulus, and shear modulus curves of kerogen, clay minerals, and other minerals, as well as the total porosity curve, and the porosity curves of organic and inorganic matter; and determining a shale rock physical model based on the dry rock density, P-wave and S-wave velocities, and shear modulus curves, and the bulk modulus and density curves of the mixed fluid. This method enables the reasonable establishment of a shale rock physical model based on the changes in organic matter during the maturation process.

The invention belongs to the technical field of multi-modal combined imaging, and discloses a multi-modal combined imaging method and platform for shale nano-pore three-dimensional reconstruction and connectivity quantitative evaluation, and aims to realize shale organic pore and inorganic pore structure three-dimensional and quantitative characterization based on FIB-SEM and X-CT. High-resolution imaging and chemical imaging technologies are used for revealing the occurrence state of kerogen in mineral particles or at the boundaries, the mineral surface catalyzes organic matter to generate hydrocarbon, and the pore evolution mechanism is regulated and controlled.

A method and system for quantitatively evaluating kerogen swelling oil in shale is provided. The method includes: establishing different types of kerogen molecular models, and loading each of the kerogen molecular models into a graphene slit-type pore composed of a lamellar structure; performing energy minimization (EM), relaxation and annealing to obtain a kerogen slit-type pore; loading a shale oil molecule into the kerogen slit-type pore to obtain an initial model of swelling and adsorption of shale oil in kerogen; assigning a value to a force field of the shale oil molecule and the kerogen molecule in the swelling and adsorption model to obtain a density of the kerogen and the shale oil; plotting a density curve of the kerogen and the shale oil; calculating kerogen swelling oil mass; determining per-unit kerogen swelling oil mass; and determining the kerogen swelling oil mass in different evolution stages.

The invention relates to the technical field of oil exploration, and provides a shale oil reservoir effective porosity determination method and device. The method comprises the following steps: acquiring target logging information to obtain the stratum density of a target stratum and the total organic carbon content of kerogen; judging whether the target logging information comprises element full-spectrum logging information or not; if yes, normalization analysis is carried out on the element full-spectrum logging information, and if not, combinatorial analysis is carried out on preset logging information in the target logging information, so that inorganic framework mineral component content information and clay content of the target stratum are obtained; calculating the density of the mixed inorganic mineral skeleton according to the mineral component content information of the inorganic skeleton; and calculating the effective porosity of the target stratum according to the stratum density, the total organic carbon content of kerogen, the mixed inorganic mineral skeleton density and the clay content. According to the embodiment of the invention, the influence of organic and inorganic mineral skeletons on the porosity can be considered, so that the calculation precision of the effective porosity of the shale oil reservoir is improved.

This invention relates to a method for determining the main gas generation threshold of cracked oil from different types of source rocks. The method is as follows: obtaining source rock samples; conducting high-temperature and high-pressure hydrocarbon generation and expulsion thermal simulation experiments in a closed system; performing total organic carbon (TOC) content and kerogen vitrinite reflectance measurements on the thermally simulated solid slag samples from the high-temperature and high-pressure hydrocarbon generation and expulsion thermal simulation experiments; plotting a cross-plot of total organic carbon content and kerogen vitrinite reflectance to obtain the maturity threshold of the main gas generation period; plotting the TOC-... T Cross-plots were used to obtain the temperature threshold for the main gas generation period; the maturity threshold and temperature threshold for the main gas generation period were verified using thermal simulation hydrocarbon production rate curves. This invention uses a "forward modeling" approach to study the main gas generation threshold of source rocks and their derived crude oil, overcoming the application drawbacks of previous "backward modeling" research methods that primarily focused on crude oil.

The invention relates to the technical field of shale gas development, and provides a graphitized shale adsorption capacity prediction method and device. The method comprises the following steps: acquiring geological feature information and pore feature information of graphitized shale in a target reservoir; selecting a target graphitized shale sample from the target reservoir, and establishing a kerogen molecular model and a shale mineral model corresponding to the target graphitized shale sample; establishing a graphitized shale model according to the kerogen molecular model and the shale mineral model; according to the graphitized shale model, establishing a corresponding graphitized shale slit model by utilizing the pore characteristic information; optimizing the graphitized shale slit model based on molecular simulation; and carrying out adsorption simulation on the optimized graphitized shale slit model by utilizing a preset adsorption molecule model to obtain the predicted adsorption quantity of the graphitized shale. According to the embodiment of the invention, the adsorption capacity of graphitized shale with different graphitization degrees can be accurately and efficiently predicted.

This invention provides a method for restoring and evaluating the original total organic carbon (TOC) parameters of source rocks based on hydrocarbon generation kinetics. This method restores residual oil content through light and heavy hydrocarbon correction, and uses kinetic parameters such as kerogen hydrocarbon generation conversion rate, crude oil cracking conversion rate, and coke formation ratio, calibrated by thermal simulation experiments, as constraints to construct an in-source cracking oil evaluation model and its material balance formula. This restores and evaluates the original S2, in-source cracking oil content, coke carbon content, and original TOC, thereby revealing the mechanism of the initial decrease followed by an increase in TOC evolution. This application provides a complete closed-loop framework from experimental calibration to geological parameter restoration, significantly improving the geological reliability of source rock resource evaluation. This method overcomes the limitations of traditional methods in interpreting TOC evolution in highly mature areas, improves the accuracy of residual oil recovery, and provides a scientific, repeatable, and verifiable technical path for source rock resource assessment.