Abo Bibliothek: Guest
Digitales Portal Digitale Bibliothek eBooks Zeitschriften Referenzen und Berichte Forschungssammlungen
Special Topics & Reviews in Porous Media: An International Journal
ESCI SJR: 0.259 SNIP: 0.466 CiteScore™: 0.83

ISSN Druckformat: 2151-4798
ISSN Online: 2151-562X

Special Topics & Reviews in Porous Media: An International Journal

DOI: 10.1615/SpecialTopicsRevPorousMedia.v5.i2.40
pages 133-143

LOW-SALINITY WATER FLOODING: EVALUATING THE EFFECT OF SALINITY ON OIL AND WATER RELATIVE PERMEABILITY, WETTABILITY, AND OIL RECOVERY

Sina Shaddel
Sahand Petroleum Research Center, Sahand University of Technology, Tabriz, Iran; RO Solutions, 7462 Trondheim, Norway
S. Alireza Tabatabae-Nejad
Sahand Petroleum Research Center, Sahand University of Technology, Tabriz, Iran
S. Jafar Fathi
Department of Petroleum Engineering, University of Stavanger, 4036 Stavanger, Norway

ABSTRAKT

Oil recovery in petroleum reservoirs is greatly affected by fluid/rock and fluid/fluid interactions. Surface chemical interactions directly control rock wettability, relative permeabilities, and capillary pressure curves. The relative permeability studies presented have been selected based on showing the impact of low-salinity water on relative permeability and wettability. First, a set of experiments was performed by flooding with formation brine until the recovery plateau was reached, then the core was restored to the initial state and low-salinity water was injected. The injecting fluid was the seawater, in which the formation water was diluted 10 and 100 times. Formation water that was diluted 100 times without divalent ions and crude oil and with different chemical properties was used. The salinity dependence of the obtained relative permeability curves and the residual oil saturations clearly indicate that changing the wetting properties of rock surfaces to a more water-wet state is an important factor in the low-salinity water effect. In addition, there was no proximate relationship between the oil relative permeability and the acid number. Core flow tests clearly show that for some crude oils the residual oil saturation obtained at the end of a waterflood depends on the salinity of the brine used.


Articles with similar content:

LOW SALINITY WATER INJECTION AT DIFFERENT RESERVOIR ROCKS: SIMILARITIES AND DIFFERENCES
Special Topics & Reviews in Porous Media: An International Journal, Vol.7, 2016, issue 1
Behzad Rostami, Kamran Hassani, M. R. Yassin, Shahab Ayatollahi
MACROSCOPIC AND MICROSCOPIC INVESTIGATION OF ALKALINE−SURFACTANT−POLYMER FLOODING IN HEAVY OIL RECOVERY USING FIVE-SPOT MICROMODELS: THE EFFECT OF SHALE GEOMETRY AND CONNATE WATER SATURATION
Journal of Porous Media, Vol.18, 2015, issue 8
Amin Mehranfar, Davood Rashtchian, Mohsen Masihi, Mohammad Hossein Ghazanfari
AN EXPERIMENTAL STUDY OF INTERACTION BETWEEN NANOPARTICLES' DEPOSITION ON A SINTERED POROUS MEDIUM AND MIGRATORY FINES
Journal of Porous Media, Vol.16, 2013, issue 5
Ali Habibi, Milad Ahmadi, Shahab Ayatollahi, Peyman Pourafshary
QUANTIFYING THE ROLE OF PORE GEOMETRY AND MEDIUM HETEROGENEITY ON HEAVY OIL RECOVERY DURING SOLVENT/CO-SOLVENT FLOODING INWATER-WET SYSTEMS
Journal of Porous Media, Vol.14, 2011, issue 4
S. Vossoughi, Ali Akbar Dehghan, Mohammad Hossein Ghazanfari, Riyaz Kharrat
MODELING THE EFFECT OF OSMOTIC POTENTIAL CHANGES ON DEFORMATION BEHAVIOR OF SWELLING CLAYS
Journal of Porous Media, Vol.13, 2010, issue 8
Karim Bendani, Hanifi Missoum, Nadia Laredj