Southwest Petroleum University

Huang Liu

Ping Guo

Zhouhua Wang

Yisheng Hu

Shuoshi Wang

Jianfen Du

Hanmin Tu

Yijian Chen

Hongmei Ren

Wanbo Zhang

Shuai Wu

Huimin Zhang

Wenhua Zhao

Nan Li

Hongnan Yang

Zhiliang Liu

Guangya Zhu

Xintong Zhang

Xingliang Deng

Yuhong Du

Ping Le

Tongwen Jiang

Zhicheng Yang

Shiyong Hu

Xuan Bai

Qinglong Xu

Zheng Gu

Ruifeng Xu

Gan Peng

Limiao Wang

A Hydrophilic-Lipophilic Deviation theory-based method is provided to prepare representative degassed oil with equivalent minimum miscible pressure to live oil. The method can reduce the number of trial and error type experiments during the representative degassed oil preparation process by measuring the MMP and EACN for dead and live oil. The representative degassed oil formulation could be easily predicted after determining the required MMP and EACN values. The prepared oil can reflect the key mechanism of multiple contact miscible mechanism in the process of gas flooding more accurately. It allows experiments that are inconvenient to use live oil to consider the mechanism of multiple contact miscibility easily.

Method of preparing degassed oil representative of live oil with equivalent minimum miscible pressure

Disclosed is a method for measuring critical condensate saturation pressure and critical condensate saturation of condensate gas by combining one-dimensional and two-dimensional nuclear magnetic resonance techniques, which solves low measurement precision and complex test method. The present invention detects signal intensity of the hydrogen-containing fluid in a rock core by combining a one-dimensional nuclear magnetic resonance Tspectrum testing technology and a two-dimensional nuclear magnetic resonance T-Tspectrum testing technology, achieves the optimization of an artificial zoning method by an improved difference spectroscopy method to reduce errors, greatly improves condensate signal identification precision, and more quickly and accurately measures the critical condensate saturation pressure and the critical condensate saturation. Therefore, the flow law of condensate oil and gas two-phases in a formation is better studied, a more reasonable development plan is favorably formulated by a gas reservoir, and theoretical guidance is provided for improving condensate recovery ratio.

Method for measuring critical condensate saturation pressure and critical condensate saturation of condensate gas by combining one-dimensional and two-dimensional nuclear magnetic resonance techniques

A method for determining a phase-state type and saturation of a fluid by an NMR technology includes putting a core to be measured to an NMR phase-state testing device, injecting a heavy water solution from both ends of a gripper at the same time until the core reaches the formation pressure, and stopping; scanning the core to obtain a two-dimensional NMR map, and determining whether the core contains a gas phase; reducing the temperature of the gripper, and collecting an oil phase volume, a gas phase volume and a water phase volume discharged from the core; purge the pipelines out with nitrogen, collecting a water phase volume and an oil phase volume in the pipelines; performing dry distillation on the core to obtain an oil phase volume and a water phase volume; and obtaining the saturations of various phases according to the fluid volumes of multiple phases in the core.

Method for determining phase-state type and saturation of fluid in tight reservoirs by NMR technology

The present invention discloses a gas based testing method for a pore volume compressibility of a low-permeability rock. The method comprises the following steps: obtaining a compressibility and an isothermal adsorption-desorption curve of experimental gas under a reservoir condition; performing a physical simulation experiment by using a steel core drilled with a through hole, and obtaining a gas volume collected due to the deformation of an experimental instrument; then repeating the experiment by using an actual core with the same size, and obtaining pore volumes of the reservoir core under the experimental conditions by deducting deformation of the instrument; and finally, obtaining a pore compressibility of the reservoir core under different reservoir conditions according to the pore volumes of the reservoir core under different reservoir conditions. The present invention considers gas adsorption, corrects errors caused by deformation of a physical simulation device.

Gas based testing method for pore volume compressibility of low-permeability rock

The invention discloses a method for evaluating the difference in gas injection effect of gas injection wells in a carbonate reservoir, aiming at solving the problem that the difference in effect characters of gas injection wells cannot be systematically evaluated in the prior art, and realizing the purposes of systematically and completely evaluating the difference in gas injection effect in the carbonate reservoir and finding out the reason of low efficiency. By means of the invention, reasons for low gas injection efficiency corresponding to different geological classifications are obtained, systematic classification and induction are carried out on the difference in gas injection effect, and gas injection effects are effectively evaluated, so that a sufficient gas injection scheme design basis is provided for subsequent development and production increase, and a significant guiding principle is provided for later-stage gas injection and production increase of the carbonate reservoir.

Method for evaluating difference in gas injection effect of gas injection wells in carbonate reservoir

A direct method for manufacturing a large model fractured core and maintaining original oil-water saturation, including the following steps: (1) determining the volume V, porosity &#x3c6;, permeability K, oil saturation S, water saturation Sand the like of a fractured core to be manufactured; (2) preparing simulated oil, and determining the used oil mass m=V&#xd7;&#x3c1;; (3) under the circumstance of no consideration of oil saturation, acquiring the mass of the used water, cement and quartz sand; (4) while establishing oil saturation, acquiring the mass mof water for manufacturing the core as m=a&#x2212;V&#xd7;&#x3c1;; (5) mixing oil, water and an emulsifier evenly to prepare an oil-in-water emulsion; (6) adding cement and quartz sand into the emulsion and stirring evenly to obtain cement slurry; (7) when a cement sample is in a semi-solidified state, cutting the cement sample with a steel wire; and (8) solidifying the cement sample to the end.

Direct method for manufacturing large model fractured core and maintaining original oil-water saturation

A manufacturing method of a big-model low-permeability microcrack core includes: (1) determining the size of a microcrack core to be manufactured; (2) placing stones in a baking oven to bake for 24h under 120&#xb0; C., placing the stones into a mixer, mixing and spraying oil, enabling the oil to seep into the stone, evenly forming a thin oil film on stone's surface; (3) mixing the oil sprayed stone with quartz sand and cement, adding water to mix evenly to obtain cement paste; (4) spreading butter on core mold's inner surface to form a thin butter film, pouring the cement paste into the core mold to obtain a cement sample; (5) loading confining pressure outside the core according to the requirements of porosity and permeability of the mold to adjust a pore permeability value; (6) obtaining the big-model core with microcrack after the cement sample is dried and formed.

Manufacturing method of big-model low-permeability microcrack core

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Chengdu, China

Huang Liu