Abstract: The present invention a method for determining the gas saturation of a tight reservoir. The method comprises the steps of: determining the pore size distribution of the tight reservoir rock sample, and calculating the free water saturation; calculating the water-membrane water saturation; calculating the corner water saturation; calculating the gas saturation of the tight reservoir rock sample according to the following equation: Sg=100?Sw wherein Sw is the water saturation in %; Sw is the sum of the free water saturation, the water saturation and the corner water saturation; Sg is the gas saturation in %. The method for determining the gas saturation of a tight reservoir uses model calculations, which avoids errors in the determination results of the gas saturation caused by water volatilization, surface adsorption, and observation of water flow during experiments.

Abstract: There is an oil and gas zone effectiveness evaluation method. The oil and gas zone effectiveness evaluation method has the steps of: obtaining a controlling factor parameter distribution of a target interval; obtaining an evaluation parameter lower limit value of an industrial oil and gas reservoir; obtaining an accumulation parameter value of each grid coordinate point according to the controlling factor parameter distribution; obtaining an evaluation parameter processing value of each grid coordinate point according to the evaluation parameter, the evaluation parameter lower limit value and the accumulation parameter value of the grid coordinate point; and obtaining a zone evaluation value of the target interval according to the evaluation parameter processing value of the grid coordinate point. There also is an apparatus that is capable of improving the evaluation coincidence rate.

Abstract: According to some implementations, the present disclosure relates to a method and apparatus for evaluating exploitation value of a geological resource. In one implementation, a method includes: acquiring geological parameters of a geological structure in multiple designated dimensions, wherein the geological parameters are used for characterizing a state of the geological structure in the designated dimensions; matching the geological parameters with a threshold of each of the designated dimensions, respectively, to obtain a characterization value of each of the designated dimensions; forming a characterization vector from the characterization values of the designated dimensions; and performing an evaluation operation based on the characterization vector to obtain an evaluation value of the geological resource in the geological structure.

Abstract: Embodiments of the present disclosure disclose a shale oil in-situ lightening development method, apparatus and system, wherein the method comprises: determining an effective shale interval according to an interval with a total organic carbon greater than a first lower limit value in a target stratum; determining a favorable region for shale oil in-situ lightening development according to a thickness of the effective shale interval and an effective layer thickness ratio, wherein the effective layer thickness ratio includes a ratio of the thickness of the effective shale interval to a thickness of a shale section, and the shale section includes the effective shale intervals and interlayers therebetween. By utilizing the embodiments of the present disclosure, the benefit of the shale oil in-situ lightening development can be improved.

Abstract: A method and an apparatus for measuring oil content of a tight reservoir based on nuclear magnetic resonance includes applying a pulse sequence to a tight reservoir rock, and after applying a first pulse and a last pulse in the pulse sequence, applying a gradient magnetic field to the tight reservoir rock, respectively, directions of the two applied gradient magnetic fields being opposite to each other, wherein the pulse sequence is composed of three 90° pulses; acquiring a nuclear magnetic resonance signal of the tight reservoir rock; and determining oil content of the tight reservoir rock according to an intensity of the nuclear magnetic resonance signal. The method can accurately distinguish an oil phase nuclear magnetic resonance signal and a water phase nuclear magnetic resonance signal in nanopores of tight reservoir rock, thereby effectively improving the accuracy of the detection result of the oil content of the tight reservoir rock.

Abstract: The present invention a method for determining the gas saturation of a tight reservoir. The method comprises the steps of: determining the pore size distribution of the tight reservoir rock sample, and calculating the free water saturation; calculating the water-membrane water saturation; calculating the corner water saturation; calculating the gas saturation of the tight reservoir rock sample according to the following equation: Sg=100?Sw wherein Sw is the water saturation in %; Sw is the sum of the free water saturation, the water saturation and the corner water saturation; Sg is the gas saturation in %. The method for determining the gas saturation of a tight reservoir uses model calculations, which avoids errors in the determination results of the gas saturation caused by water volatilization, surface adsorption, and observation of water flow during experiments.

Abstract: The invention provides a method for determining oil contents in rocks. The method comprises steps of: measuring a plurality of calibration oil samples having different oil contents, and acquiring a holographic fluorescence spectral intensity corresponding to the calibration oil samples; acquiring a fit relation between the holographic fluorescence spectral intensity and the oil contents of the calibration oil, according to the oil contents of the plurality of calibration oil samples and a plurality of three-dimensional fluorescence spectral intensities corresponding thereto; adding a certain amount of the calibration oil after dilution to rocks to be measured, acquiring a sample of the rocks to be measured and performing a holographic fluorescence measurement of the rock sample to be measured; and introducing the holographic fluorescence spectral intensity of the rock sample to be measured to the fit relation, thus an oil content of the rock sample to be measured is obtained.

Abstract: Embodiments of the present disclosure disclose a shale oil in-situ lightening development method, apparatus and system, wherein the method comprises: determining an effective shale interval according to an interval with a total organic carbon greater than a first lower limit value in a target stratum; determining a favorable region for shale oil in-situ lightening development according to a thickness of the effective shale interval and an effective layer thickness ratio, wherein the effective layer thickness ratio includes a ratio of the thickness of the effective shale interval to a thickness of a shale section, and the shale section includes the effective shale intervals and interlayers therebetween. By utilizing the embodiments of the present disclosure, the benefit of the shale oil in-situ lightening development can be improved.

Abstract: A device and method of determining thermal maturity of oil source rocks by total scanning fluorescence including testing the organic solution of the extract from a series of oil source rock samples collected at different depths by total scanning fluorescence; building a model for interpretation of the oil source rock maturity according to the variation with depth of the TSF Intensity parameter and the TSF R1 parameter obtained by total scanning fluorescence, and identifying the stage of initial oil generation, the stage of major oil generation and the stage of major gas generation; and establishing the relationship between the TSF Intensity parameter and/or the TSF R1 parameter with the existing characteristic parameters that quantitatively characterize the maturity of oil source rocks, thereby accomplishing the analysis and determination of the maturity of the oil source rocks.

Abstract: A device and method of determining thermal maturity of oil source rocks by total scanning fluorescence including testing the organic solution of the extract from a series of oil source rock samples collected at different depths by total scanning fluorescence; building a model for interpretation of the oil source rock maturity according to the variation with depth of the TSF Intensity parameter and the TSF R1 parameter obtained by total scanning fluorescence, and identifying the stage of initial oil generation, the stage of major oil generation and the stage of major gas generation; and establishing the relationship between the TSF Intensity parameter and/or the TSF R1 parameter with the existing characteristic parameters that quantitatively characterize the maturity of oil source rocks, thereby accomplishing the analysis and determination of the maturity of the oil source rocks.

Abstract: A method and an apparatus for measuring oil content of a tight reservoir based on nuclear magnetic resonance includes applying a pulse sequence to a tight reservoir rock, and after applying a first pulse and a last pulse in the pulse sequence, applying a gradient magnetic field to the tight reservoir rock, respectively, directions of the two applied gradient magnetic fields being opposite to each other, wherein the pulse sequence is composed of three 90° pulses; acquiring a nuclear magnetic resonance signal of the tight reservoir rock; and determining oil content of the tight reservoir rock according to an intensity of the nuclear magnetic resonance signal. The method can accurately distinguish an oil phase nuclear magnetic resonance signal and a water phase nuclear magnetic resonance signal in nanopores of tight reservoir rock, thereby effectively improving the accuracy of the detection result of the oil content of the tight reservoir rock.

Abstract: The present invention provides an oil and gas zone effectiveness evaluation method and apparatus.

Abstract: According to some implementations, the present disclosure relates to a methods and apparatus for evaluating exploitation value of a geological resource. In one implementation, a method includes: acquiring geological parameters of a geological structure in multiple designated dimensions, wherein the geological parameters are used for characterizing a state of the geological structure in the designated dimensions; matching the geological parameters with a threshold of each of the designated dimensions, respectively, to obtain a characterization value of each of the designated dimensions; forming a characterization vector from the characterization values of the designated dimensions; and performing an evaluation operation based on the characterization vector to obtain an evaluation value of the geological resource in the geological structure.