10 results about "Kerogen" patented technology

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.

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.

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 application relates to the technical field of oil exploration, and provides a method and device for determining effective porosity of a shale oil reservoir. The method comprises the following steps: obtaining target well logging data to obtain formation density and total organic carbon content of a target formation; determining whether the target well logging data comprises element full spectrum logging data; if yes, performing normalization analysis on the element full spectrum logging data, and if not, performing combined analysis on preset well logging data in the target well logging data to obtain inorganic framework mineral component content information and clay content of the target formation; calculating mixed inorganic mineral framework density according to the inorganic framework mineral component content information; and calculating effective porosity of the target formation by using the formation density, the total organic carbon content of the dry kerogen, the mixed inorganic mineral framework density and the clay content. According to the embodiment of the application, the influence of organic and inorganic mineral frameworks on porosity can be considered, so that the calculation precision of the effective porosity of the shale oil reservoir is improved.

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.

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.

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.