PVT and Fluid Phase Behavior for Enhanced Oil Recovery of Liquid-Rich Unconventional Reservoirs Presentation
August 14, 2018
The thermodynamic behavior of a reservoir fluid depends strongly on pressure, temperature and composition. At given reservoir temperature and different pressures, the components may be distributed between phases. Phase behavior and the actual volumetric contribution of each phase to the system play an important role in quantifying fluid flow through porous media.
Reservoirs were often produced by primary depletion in which the reservoir pressure was the main variable that controlled the fluid properties, such as compressibility, density, formation volume factor, and gas-oil ratio. This is especially important for low-permeability oil reservoirs which will produce gas, oil, and water in time-dependent proportions due to hydraulic fracture stimulation and bottom-hole flowing pressures below bubble-point pressure.
Gas and oil properties are required to determine the oil and gas volumes in-place, to properly quantify flowing properties of each phase, and to predict future production rates and recovery. Multiphase fluid flow behavior of near-critical fluids varies substantially depending on the size of the pore throats. The effect of capillarity and adsorption will be important in the gas-oil equilibrium in nanoscale porous media which requires using the thermodynamics of curved surfaces.
In addition, gas injection, under the proper conditions of pressure and temperature, and favorable reservoir oil composition, can become miscible with the oil, helping remobilize and produce the oil remaining in the liquid-rich shale reservoirs. In order to design a successful gas injection project, it is important to understand the physics and mechanisms by which the injected gas displaces oil in porous medium.
In this presentation, the PVT and phase behavior of hydrocarbon systems by various advanced PVT experiments along with their importance in building an accurate EOS model are reviewed. The accuracy of any EOS model depends on the quality of the laboratory PVT data and procedures used to obtain the EOS parameters especially in the design of gas injection EOR for liquid-rich unconventional reservoirs. A modified black-oil model suitable for shale reservoirs using EOS parameters generated from curved surface thermodynamics will be also discussed.PVT and Fluid Phase Behavior for Enhanced Oil Recovery of Liquid-Rich Unconventional Reservoirs Presentation
August 14th, 2018Time:
DoubleTree by Hilton Hotel Midland Plaza, 117 W Wall St, Midland, TX 79701 Presenter:
Dr. Edmond Shtepani is Vice President of Intertek Upstream Services and Director of Intertek Westport Technology Center, Houston, Texas, one of the largest integrated laboratories in the world focused on Exploration and Production solutions.
Prior joining Intertek, he has been the Engineering Manager/Chief Research Engineer at Hycal Energy Research Laboratories, a Weatherford Company, based in Calgary, Alberta, Canada. He has over 25 years of international technical expertise in the area of EOR/IOR methods, Compositional Reservoir Simulation, PVT and Fluid Phase Behavior, EOS Modeling and Characterization, Special Core Analysis (SCAL), Formation Damage, Rock Mechanics, and Flow Assurance.
He holds a B.Sc. and M.Sc. in Physics from University of Tirana, Albania and Technical University of Vienna, Austria, and a Ph.D. in Reservoir Engineering from University of Leoben, Austria. For several years he has lectured at the Polytechnic University of Tirana, the University of Leoben and at the University of Calgary, Alberta, Canada. He has author/co-authored a number of technical papers and presentations and has participated in multiple in-house training programs and has taught industry short courses in the area of his expertise. He is a member of SPE, SCA, Editorial Review Committee of SPE Reservoir Evaluation & Engineering and of Journal of Petroleum Science and Engineering. He is a member of Professional Engineers, Geologists and Geophysicists of Alberta, Canada.