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Yao T.,China University of Petroleum - East China | Huang Y.,CAS Institute of Porous Flow and Fluid Mechanics | Li J.,Geological Scientific Research Institute of Shengli Oilfield Co.
Lixue Xuebao/Chinese Journal of Theoretical and Applied Mechanics | Year: 2012

The research on flow mechanism and productivity evaluation of shale gas is still in its infancy. Based on the complex pore structure of shale gas reservoir, slip flow and adsorption-desorption of shale gas, Darcy model is modified. Compared with the Darcy model in production steady case, the bottom hole pressure based on non-Darcy flow model is higher than that from the Darcy flow; the pressure from the Darcy flow model decays more exaggerated and than predicted well life was shorter. The modified flowing model can describe and characterize shale gas flowing process more accurately. The results can provide basic parameters for the operation and management of the shale gas reservoir. Source


Yao T.,China University of Petroleum - East China | Huang Y.,CAS Institute of Porous Flow and Fluid Mechanics | Li J.,Geological Scientific Research Institute of Shengli Oilfield Co.
Lixue Xuebao/Chinese Journal of Theoretical and Applied Mechanics | Year: 2012

The gas flow characteristic in an adsorbent bed is a vital problem for further studying the mechanics of gas separation process. In this paper, a comprehensive mathematical model of gas flow and adsorption in an adsorbing bed, which based on mass and momentum conservation law, is established. A typical cyclic process of an axial-flow rapid pressure swing adsorption is numerically studied. The flow patterns in different cyclic period for pressurization, adsorption, depressurization, desorption and purge, are obtained. The flow characteristics and their difference from the gas flow in an empty bed and a no-adsorption bed are also studied. Source


Qin J.,Petrochina | Zhang K.,CAS Institute of Porous Flow and Fluid Mechanics | Chen X.,Petrochina
Shiyou Xuebao/Acta Petrolei Sinica | Year: 2010

Aiming at problems of low or no efficiency of water flooding in high water cut reservoirs or stagnant zones, the present paper studied the mechanism of supercritical CO2 miscible flooding, migration characteristics of oil film and the mass transfer process between CO2 and oil by using a high-speed, advanced and visualized camera micro-simulation model, by which the displacement mechanism of transient blind side was observed, and the film migration phenomenon and the mixed phase were also seen. The results have shown that the wax in crude oil continues to be deposited at pore throats and chock up throats, while supercritical CO2 can surpass water hindrance in pores and further flood the residual oil away in the form of both the cylindrical and columnar flow. Supercritical CO2 has a strong ability to dissolve oil due to the occurrence of molecular aggregation within it. What is more, it could extract not only light hydrocarbon components but also certain heavy hydrocarbon components from crude oil. Thus, supercritical CO2 is a kind of good miscible agents for flooding crude oil. Source


Yang P.,University of Regina | Guo H.,CAS Institute of Porous Flow and Fluid Mechanics | Yang D.,University of Regina
Energy and Fuels | Year: 2013

The NMR relaxometry measurements have been designed and applied to quantitatively determine residual oil distribution during waterflooding in tight oil formations. A tight core sample is first saturated with water to measure its NMR transverse relaxation time (T2) spectrum. NMR T2 spectrum is then measured for the core sample after it has been displaced with the fluorinated oil. Subsequently, the core sample is displaced with water until residual oil saturation is achieved, and the NMR T2 spectrum is measured again at the end of the displacement. Subsequently, the constant-rate mercury injection method is used to experimentally measure the size of the pore and throat in the core sample. The residual oil saturation is determined as a function of pore size by comparing the difference between the first and last NMR T2 spectrum. It is found from four core samples with permeability of 0.04-1.70 mD that the average pore size is in a range of 129-145 μm, and the pore throat has a radius of 0.17-0.89 μm. The original oil saturation is found to be 76-83%, whereas the oil recovery factor is 36-62%; 4-27% of the original oil is distributed in pores larger than 100 μm, 50-54% in pores from 10 to 100 μm, and 21-46% in pores and throats smaller than 10 μm. Residual oil saturation is 1-2% in pores larger than 100 μm, 29-64% in pores from 10 to 100 μm, and 34-69% in pores and throats smaller than 10 μm. © 2013 American Chemical Society. Source


Wang J.,CAS Institute of Porous Flow and Fluid Mechanics | Yu L.,China National Petroleum Corporation | Huang L.-X.,China National Petroleum Corporation
Petroleum Science and Technology | Year: 2011

The feasibility of enhancing oil recovery in Qinghai oilfield with hypersalinity was studied. The results showed that main microbial populations in the reservoir were saprophytic, hydrocarbon-oxidizing, fermentative, nitrate-reducing bacteria and methanogens. The indigenous microorganisms preferentially used nitrogen sources for emulsification, the gas-liquid ratio was 0.20, pressure reached 0.27 MPa; saturated hydrocarbon was catalyzed selectivity. The species isolated were confirmed as Oceanobacillus sp. and Staphylococcus sp.; the oil recovery was 8.42%, which shows great potential to enhance oil recovery. Copyright © Taylor & Francis Group, LLC. Source

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