Effects of Pore Pressure and Two-Phase Flow on Permeability Estimation of Reservoir Rock

2016 ◽  
Author(s):  
Saad F. Alkafeef ◽  
Hamid Hadibeik ◽  
Mehdi Azari ◽  
Mohamed K. El-Daou
Keyword(s):  
Pore Pressure ◽  
Two Phase Flow ◽  
Reservoir Rock ◽  
Phase Flow ◽  
Two Phase ◽  
Permeability Estimation

The Modeling for Coupled Elastoplastic Geomechanics and Two-Phase Flow With Capillary Hysteresis in Porous Media

2021 ◽  
Author(s):  
H. C. Yoon ◽  
J. Kim
Keyword(s):  
Pore Pressure ◽  
Two Phase Flow ◽  
Irreversible Processes ◽  
Well Posedness ◽  
Phase Flow ◽  
Two Phase ◽  
Capillary Hysteresis ◽  
Fluid Content ◽  
Plastic Fluid ◽  
Multi Phase

Abstract We study new constitutive relations employing the fundamental theory of elastoplasticity for two coupled irreversible processes: elastoplastic geomechanics and two-phase flow with capillary hysteresis. The fluid content is additively decomposed into elastic and plastic parts with infinitesimal transformation assumed. Specifically, the plastic fluid content, i.e., the total residual (or irrecoverable) saturation, is also additively decomposed into constituents due to the two irreversible processes: the geomechanical plasticity and the capillary hysteresis. The additive decomposition of the plastic fluid content facilitates combining the existing two individual simulators easily, for example, by using the fixed-stress sequential method. For pore pressure of the fluid in multi-phase which is coupled with the geomechanics, the equivalent pore pressure is employed, which yields the well-posedness of coupled multi-phase flow and geomechanics, regardless of the capillarity. We perform an energy analysis to show the well-posedness of the proposed model. And numerical examples demonstrate stable solutions for cyclic imbibition/drainage and loading/unloading processes. Employing the van Genuchten and the Drucker Prager models for capillary and the plasticity, respectively, we show the robustness of the model for capillary hysteresis in multiphase flow and elastoplastic geomechanics.

Vacuum pressure distribution and pore pressure variation in ground improved by vacuum preloading

2007 ◽  
Vol 44 (12) ◽  
pp. 1433-1445 ◽  
Author(s):  
Q. C. Qiu ◽  
H. H. Mo ◽  
Z. L. Dong
Keyword(s):  
Pore Pressure ◽  
Single Phase ◽  
Two Phase Flow ◽  
Vacuum Pressure ◽  
Phase Flow ◽  
Water Mixture ◽  
Pressure Reduction ◽  
Treatment Area ◽  
Vacuum Preloading ◽  
Two Phase

This paper presents the difference between vacuum pressure and pore pressure reduction for vacuum preloading projects. The experimental results show that the pattern of the fluid flow under vacuum pressure can be classified into three categories—a single-phase water flow, an air–water two-phase flow, and a single-phase air flow. The field test results show that the vacuum pressure reaches the highest value at the ground level and the measured gradients of the vacuum pressure in the vertical direction are approximately 11 kPa/m. It is demonstrated that (i) the treatment area of vacuum preloading cannot be sealed and does not need to be airtight, (ii) the air–water mixture is drawn out from the treatment area under vacuum pressure and the groundwater level drops owing to the presence of air in practice, and (iii) there is an air–water two-phase flow in the unsaturated zone during preloading. The study shows that (i) the vacuum pressure is only a part of the pore pressure reduction along the depth of improving soil; and (ii) the vacuum pressure induces the soil to undergo isotropic consolidation, whereas the pore pressure reduction that is greater than the atmospheric pressure induces the soil to undergo one-dimensional consolidation.

scholarly journals Relative permeability estimation of oil-water two-phase flow in shale reservoir

2021 ◽  
Author(s):  
Yu-Liang Su ◽  
Ji-Long Xu ◽  
Wen-Dong Wang ◽  
Han Wang ◽  
Shi-Yuan Zhan
Keyword(s):  
Relative Permeability ◽  
Two Phase Flow ◽  
Phase Flow ◽  
Two Phase ◽  
Permeability Estimation ◽  
Shale Reservoir ◽  
Oil Water

scholarly journals Real-time estimation of reservoir influx rate and pore pressure using a simplified transient two-phase flow model

2016 ◽  
Vol 32 ◽  
pp. 439-452 ◽  
Author(s):  
Adrian Ambrus ◽  
Ulf Jakob Flø Aarsnes ◽  
Ali Karimi Vajargah ◽  
Babak Akbari ◽  
Eric van Oort ◽  
...  
Keyword(s):  
Real Time ◽  
Pore Pressure ◽  
Flow Model ◽  
Two Phase Flow ◽  
Time Estimation ◽  
Phase Flow ◽  
Two Phase ◽  
Influx Rate ◽  
Real Time Estimation
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