Educational Qualification
|
- PhD in Chemical Engineering (July 2016 - Present)
- Institute: Indian Institute of Technology Delhi, New Delhi, India
- Thesis Title: Characterization of reservoir flow properties by pore
scale simultion and experiments
- Thesis Advisor: Prof. Vivek V. Buwa and Prof. Jyoti Phirani
- M.Tech in Energy Engineering (July 2014 – June 2016)
- Institute: National Institute of Technology Trichy,
Tamilnadu, India
- B.E. in Chemical Engineering (July 2009 – June 2013)
- Institute: University of Pune, Maharashtra, India
|
Research Interests |
- Computational Fluid Dynamics
- Multiphase Flows through porous media
- Laser induced flourescence
- High speed imaging
|
Publications
|
International Journals |
-
Ambekar A. S., Sivakumar R., Anantharaman N., Vivekenandan M., CFD
simulation study of shell and tube heat exchangers with different
baffle segment configurations. Applied Thermal Engineering. 2016 Sep
5;108:999-1007.
|
International and National Conferences
|
-
Ambekar, A. S.,
Buwa V. V. and Phirani, J., Interface Dynamics during two phase flow in
stratified porous medium, International Conference on Nanochannels,
Microchannels and Minichannels (ICNMM 2018), Dubrovinik, Croatia.
-
Ambekar, A. S., Phirani, J. and Buwa V.
V., Pore-resolved Simulations of Two-Phase Flow through Porous
Media,
International Conference on Multiphase Flow (ICMF 2019), Rio de
Janeiro, Brazil.
-
Ambekar, A. S., Ashraf, S. and Phirani,
J., Dynamics of forced imbibition in interacting pores,
ASME - JSME - KSME Joint Fluids Engineering Conference (AJKFluids
2019),
American Society of Mechanical Engineers,
San Francisco, USA.
-
Ambekar, A. S. and Buwa, V.V.,
Pore-resolved Two-Phase Flow in a
Pseudo-3D Porous Medium: Volume of Fluid Simulations and
Experimental Validation,
ISHMT-ASTFE Heat and Mass Transfer Conference (IHMTC 2019), IIT
Roorkee, India.
|
Doctoral Dissertation Topic: Characterization of reservoir flow
properties through pore-scale simulation and experiments |
Water-flooding of oil reservoirs is the most
popular secondary oil recovery process. It accounts for 25 to 30 % of
total oil recovery. In this process pressurized water is injected
from the injection well into the oil reservoir and oil is recovered from
the production well. Upstream oil industry use reservoir scale
simulations to predict oil production. These simulations require several
reservoir properties, (e.g.. porosity and permeability) fluid properties
(e.g., viscosity and interfacial tension) and interaction flow
properties (e.g., relative permeability) as input parameters to predict
oil recovery.
Relative permeability data is generally generated from core flooding
experiments of very small rock samples, ignoring the heterogeneous
structure of reservoir rock. For accurate prediction of oil recovery, it is
necessary to determine effect of heterogeneity on oil-water relative
permeability.
Oil-water relative permeability is a function of local saturation.
Measurements of dynamics of local saturation in a reservoir is
challenging as the reservoir is opaque in nature. Here, we mimic
porous media using refractive index matched solids and liquids to
measure local saturation using high speed imaging and laser induced
fluorescence (LIF) at pore-scale. This pore-scale phenomenon of
water-flooding will be simulated using Volume of fluid (VOF) model and
validated by the LIF experiments. The pore-scale pressure data generated by VOF
simulations will be used to determine the macroscopic relative
permeability by appropriate upscaling. This macroscopic relative
permeability would be further verified using conventional core flooding experiments.
![](clip_image002.jpg)
Core flooding experimental setup used to determine oil-water relative
permeability
|
|