A Laboratory Approach To Evaluate the Efficiency of Low Salinity Brine Injection for Enhancing Oil Recovery at High Temperature in Carbonate Reservoirs
- N. Blin (CEPSA) | J. Montes Ruiz (CEPSA) | R. Rodriguez Pardo (CEPSA)
- Document ID
- Society of Exploration Geophysicists
- SEG/AAPG/EAGE/SPE Research and Development Petroleum Conference and Exhibition, 9-10 May, Abu Dhabi, UAE
- Publication Date
- Document Type
- Conference Paper
- 12 - 15
- 2018. Society of Exploration Geophysicists
- water injection, salinity, carbonate, wettability
- 2 in the last 30 days
- 28 since 2007
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This document is an expanded abstract.
During the last two decades, low salinity water injection has been studied for enhanced oil recovery in sandstone and carbonate reservoirs. Several theories about low salinity mechanisms have being proposed including wettability alteration (Buckley and Morrow, 2010).
This paper presents flooding experiments that study the impact of different salinity brines on the wettability in a carbonate reservoir. The coreflood experiments were performed at high temperature, 120ºC, at which few references can be found. Our results reveal that synthetic seawater is more favorable than formation water to increase oil recovery in both, secondary and tertiary recovery modes at high temperature in carbonate rocks. Moreover, in secondary mode the recovered oil is produced faster with synthetic seawater.
Our approach was to study the alteration of rock wettability in unsteady state (USS) coreflood experiments. We modified different parameters trying to answer these questions:
- Does aging impact the relative permeability end point?
- What is the efficiency of lowering injection brine salinity on an aged core at 120ºC?
- Does the crude oil total acid number (TAN) play a role in the oil wettability of the rock at 120ºC?
- What is the influence of salinity in the final recovery?
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