TY  - JOUR
T1  - Numerical Simulation of High Viscous Oil Recovery by
Low-Salinity Water Injection
AU - K. Turgazinov, Ilyas AU - A. Ensepbayev, Talgat 
JO  - Journal of Engineering and Applied Sciences
VL  - 13
IS  - 9
SP  - 2780
EP  - 2785
PY  - 2018
DA  - 2001/08/19
SN  - 1816-949x
DO  - jeasci.2018.2780.2785
UR  - https://makhillpublications.co/view-article.php?doi=jeasci.2018.2780.2785
KW  - Low salinity waterflooding
KW  -numerical simulation
KW  -fines migration
KW  -oil production
KW  -viscous oil
KW  -brine
AB  - Today the recovery factor in sandstone and carbonate reservoirs not exceeds 40% and in several
cases not more that 30% (reservoirs with heavy oil). In these cases, traditional waterflooding when formation
brine is injected has run out of its possibility. However, depending on the reservoir conditions a number of EOR
methods can be applied to improve oil recovery. The low salinity waterflooding is one of the latest Improved
Oil Recovery (IOR) methods. In literature it is known as ‘Smart wateflood’, ‘LoSal’ and ‘Advanced ion
Management’. This method implies reduction of the salinity of injected water. This technique demonstrated
increased oil recovery up to 40%. Most researches have shown positive results in secondary and tertiary low
salinity injection modes. Many mechanisms have been proposed to be behind improved oil recovery due to
LSW. However, wettability alteration and fine migration is believed to be main reasons. Complex interactions
between oil/brine/rock in carbonate and sandstone rocks don’t allow predicting the amount of incremental oil
because of LSWF. Nowadays there are only few papers dedicated to the possibility of implementation of LSW
in heavy oil sandstone reservoirs. The objective of this study is to use simulator and investigate the injection
of low salinity water injection into reservoirs with heavy oil in secondary mode. As a result LSW yielded up
to 18% of incremental oil recovery compared to traditional formation brine flooding.
ER  -