Petrochina Company Limited

China University of Petroleum

Keyu Liu

Hua Tian

Caineng Zou

Xuesong Lu

Mengjun Zhao

Shuichang Zhang

Shaobo Liu

Junjia Fan

Xiuli Li

Yanjie Gong

Qingong Zhuo

Xingzhi Ma

Bin Zhang

Wei Yang

Jing Hu

Jin Lai

Lin Wei Jiang

Zhichao Yu

Lili Gui

Qingyang Meng

Leilei Yang

Donghua Chen

Guo Wei

Weiquan Zhao

Jianliang Liu

Xianglu Tang

Peiqiang Yang

The present disclosure provides a method for recovering a porosity evolution process of sequence stratigraphy of carbonate rocks. The method comprises: a step of establishing a sequence stratigraphic framework of carbonate rocks; a step of dividing diagenetic stages; a step of simulating diagenesis and porosity evolution with increasing reservoir thickness and continuous superposition of multiple reservoirs during cyclic rise and fall of sea level to obtain a simulation result; and a step of calculating the porosity evolution in space over time by using the simulation result as initial values for simulation of diagenetic evolution process and simulating in stages and continuity the multi-stage diagenetic evolution process that the carbonate rock strata undergo after sediment based on the divided diagenetic stages. Compared with the traditional recovery of single reservoir porosity with time evolution, the method fully considers the superposition effect of multiple upper reservoirs in the process of reservoir sedimentary-diagenesis.

Method for recovering porosity evolution process of sequence stratigraphy of carbonate rocks

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&#xb0; 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.

Method and apparatus for measuring oil content of tight reservoir based on nuclear magnetic resonance

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. Accordingly, oil is detectable together with an organic solvent without volatilization of the organic solvent, which not only saves time, but also address a low-detection-limit problem for oil content resulting from volatilization of oil when the organic solvent is volatilized in the conventional method.

Method for determining oil contents in rock formations

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 Rparameter 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 Rparameter 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.

Method for determining maturity in oil source rock by total scanning fluorescence and the device therefor

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Beijing, China

Keyu Liu