Modification and Application of Capillary Number to Oil Displacement in Low Permeability Reservoirs

2013 ◽  
Vol 868 ◽  
pp. 522-528
Author(s):  
Tao Ping Chen ◽  
Biao Qiu ◽  
Qi Hao Hu
Keyword(s):  
Number Theory ◽  
Interfacial Tension ◽  
Capillary Number ◽  
Water Flooding ◽  
Low Permeability ◽  
Oil Displacement ◽  
Displacement Experiments ◽  
Low Interfacial Tension ◽  
Oil Water ◽  
Low Permeability Reservoirs

As concerning the limitations of the classic capillary number theory in the applications to the oil displacement with the ultra low interfacial intension system in low permeability reservoirs, considering the flow velocity of water/oil displacement through pores in low permeability reservoirs and the mechanism of displacement of the remaining oil in the parallel pores, and considering the influences of ultra low interfacial intension on oil/water relative permeability and the influences of non-homogeneity on the recovery, the expression of modification of the capillary number was given. The relation curves of recovery and capillary number were plotted through the displacement experiments with the ultra low interfacial intension system in low permeability cores. Some points on the application of capillary number to the oil displacement with the ultra low interfacial tension system were given, and the reasonable ways of enhancing the recovery of water flooding low permeability reservoirs with ultra low interfacial intension system were shown.

Evaluation of New Active Polymer Systems

2013 ◽  
Vol 848 ◽  
pp. 7-10
Author(s):  
Jia Bin Tang ◽  
Wen Xiang Wu ◽  
Zhu Xin Zhang
Keyword(s):  
Interfacial Tension ◽  
Polymer Solution ◽  
Simulation Experiment ◽  
Physical Simulation ◽  
Low Permeability ◽  
Displacement Effect ◽  
Polymer Systems ◽  
Oil Displacement ◽  
Low Permeability Reservoirs ◽  
Better Than

Using the physical simulation experiment, for the new active polymers, common carve and polymer 25 million to act on interfacial tension test, the results indicate, interfacial tension for common carve and polymer 25 million is about 10 mn/m. and interfacial tension for the active polymer is about 1 mn/m. Rheology showed that the viscosity and elasticity of active polymer solution were higher than 25 million polymer.In liquidity experiment, active polymer solution has the better liquidity than in 25 million polymers in the low permeable formation,the flooding effect of active polymer is better than 25 million polymer and common carve polymer.the better injection and better oil displacement features of active polymer are suitable for low permeability reservoirs to improve oil displacement effect.

scholarly journals Mechanism of active silica nanofluids based on interface-regulated effect during spontaneous imbibition

2021 ◽  
Author(s):  
Xu-Guang Song ◽  
Ming-Wei Zhao ◽  
Cai-Li Dai ◽  
Xin-Ke Wang ◽  
Wen-Jiao Lv
Keyword(s):  
Contact Angle ◽  
Interfacial Tension ◽  
Oil Recovery ◽  
Dynamic Contact Angle ◽  
Liquid Interface ◽  
Spontaneous Imbibition ◽  
Wettability Alteration ◽  
Low Permeability ◽  
Oil Water ◽  
Solid Liquid

AbstractThe ultra-low permeability reservoir is regarded as an important energy source for oil and gas resource development and is attracting more and more attention. In this work, the active silica nanofluids were prepared by modified active silica nanoparticles and surfactant BSSB-12. The dispersion stability tests showed that the hydraulic radius of nanofluids was 58.59 nm and the zeta potential was − 48.39 mV. The active nanofluids can simultaneously regulate liquid–liquid interface and solid–liquid interface. The nanofluids can reduce the oil/water interfacial tension (IFT) from 23.5 to 6.7 mN/m, and the oil/water/solid contact angle was altered from 42° to 145°. The spontaneous imbibition tests showed that the oil recovery of 0.1 wt% active nanofluids was 20.5% and 8.5% higher than that of 3 wt% NaCl solution and 0.1 wt% BSSB-12 solution. Finally, the effects of nanofluids on dynamic contact angle, dynamic interfacial tension and moduli were studied from the adsorption behavior of nanofluids at solid–liquid and liquid–liquid interface. The oil detaching and transporting are completed by synergistic effect of wettability alteration and interfacial tension reduction. The findings of this study can help in better understanding of active nanofluids for EOR in ultra-low permeability reservoirs.

Performance of alkali-free natural petroleum sulfonates: Ultra-low interfacial tension on oil/water interface

2015 ◽  
Vol 93 (8) ◽  
pp. 1410-1415 ◽  
Author(s):  
Zhan Weng ◽  
Peng-Yuan Zhang ◽  
Guang-Wen Chu ◽  
Wei Wang ◽  
Jimmy Yun ◽  
...  
Keyword(s):  
Interfacial Tension ◽  
Water Interface ◽  
Low Interfacial Tension ◽  
Oil Water

A COMPREHENSIVE MODEL FOR OIL–WATER RELATIVE PERMEABILITIES IN LOW-PERMEABILITY RESERVOIRS BY FRACTAL THEORY

Fractals ◽  
2020 ◽  
Vol 28 (03) ◽  
pp. 2050055
Author(s):  
HAIBO SU ◽  
SHIMING ZHANG ◽  
YEHENG SUN ◽  
XIAOHONG WANG ◽  
BOMING YU ◽  
...  
Keyword(s):  
Fractal Dimension ◽  
Capillary Pressure ◽  
Relative Permeability ◽  
Fractal Theory ◽  
Low Permeability ◽  
Comprehensive Model ◽  
Relative Permeabilities ◽  
Oil Water ◽  
Seepage Characteristics ◽  
Low Permeability Reservoirs

Oil–water relative permeability curve is an important parameter for analyzing the characters of oil and water seepages in low-permeability reservoirs. The fluid flow in low-permeability reservoirs exhibits distinct nonlinear seepage characteristics with starting pressure gradient. However, the existing theoretical model of oil–water relative permeability only considered few nonlinear seepage characteristics such as capillary pressure and fluid properties. Studying the influences of reservoir pore structures, capillary pressure, driving pressure and boundary layer effect on the morphology of relative permeability curves is of great significance for understanding the seepage properties of low-permeability reservoirs. Based on the fractal theory for porous media, an analytically comprehensive model for the relative permeabilities of oil and water in a low-permeability reservoir is established in this work. The analytical model for oil–water relative permeabilities obtained in this paper is found to be a function of water saturation, fractal dimension for pores, fractal dimension for tortuosity of capillaries, driving pressure gradient and capillary pressure between oil and water phases as well as boundary layer thickness. The present results show that the relative permeabilities of oil and water decrease with the increase of the fractal dimension for tortuosity, whereas the relative permeabilities of oil and water increase with the increase of pore fractal dimension. The nonlinear properties of low-permeability reservoirs have the prominent significances on the relative permeability of the oil phase. With the increase of the seepage resistance coefficient, the relative permeability of oil phase decreases. The proposed theoretical model has been verified by experimental data on oil–water relative permeability and compared with other conventional oil–water relative permeability models. The present results verify the reliability of the oil–water relative permeability model established in this paper.

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