Improving Gas Flooding Efficiency

Technical Report · Mon Mar 31 00:00:00 EDT 2008

DOI:https://doi.org/10.2172/953470· OSTI ID:953470

Grigg, Reid; Svec, Robert; Zeng, Zheng; Mikhalin, Alexander; Lin, Yi; Yin, Guoqiang; Ampir, Solomon; Kassim, Rashid

This study focuses on laboratory studies with related analytical and numerical models, as well as work with operators for field tests to enhance our understanding of and capabilities for more efficient enhanced oil recovery (EOR). Much of the work has been performed at reservoir conditions. This includes a bubble chamber and several core flood apparatus developed or modified to measure interfacial tension (IFT), critical micelle concentration (CMC), foam durability, surfactant sorption at reservoir conditions, and pressure and temperature effects on foam systems.Carbon dioxide and N{sub 2} systems have been considered, under both miscible and immiscible conditions. The injection of CO2 into brine-saturated sandstone and carbonate core results in brine saturation reduction in the range of 62 to 82% brine in the tests presented in this paper. In each test, over 90% of the reduction occurred with less than 0.5 PV of CO{sub 2} injected, with very little additional brine production after 0.5 PV of CO{sub 2} injected. Adsorption of all considered surfactant is a significant problem. Most of the effect is reversible, but the amount required for foaming is large in terms of volume and cost for all considered surfactants. Some foams increase resistance to the value beyond what is practical in the reservoir. Sandstone, limestone, and dolomite core samples were tested. Dissolution of reservoir rock and/or cement, especially carbonates, under acid conditions of CO2 injection is a potential problem in CO2 injection into geological formations. Another potential change in reservoir injectivity and productivity will be the precipitation of dissolved carbonates as the brine flows and pressure decreases. The results of this report provide methods for determining surfactant sorption and can be used to aid in the determination of surfactant requirements for reservoir use in a CO{sub 2}-foam flood for mobility control. It also provides data to be used to determine rock permeability changes during CO{sub 2} flooding due to saturation changes, dissolution, and precipitation.

• Research Organization: New Mexico Institute Of Mining & Techology
• Sponsoring Organization: USDOE
• DOE Contract Number: FC26-04NT15532
• OSTI ID: 953470
• Country of Publication: United States
• Language: English

Related Subjects

59 BASIC BIOLOGICAL SCIENCES
99 GENERAL AND MISCELLANEOUS//MATHEMATICS, COMPUTING, AND INFORMATION SCIENCE
ADSORPTION
BRINES
BUBBLE CHAMBERS
CARBONATES
CONTROL
COST
DATA
DISSOLUTION
DOLOMITE
EFFICIENCY
EQUIPMENT
FIELD TESTS
FLOODS
FOAMS
INJECTION
LIMESTONE
MOBILITY
OILS
PERMEABILITY
POTENTIALS
PRECIPITATION
PRODUCTION
PRODUCTIVITY
RANGE
REDUCTION
RESERVOIR ROCK
ROCKS
SANDSTONES
SATURATION
SORPTION
SURFACTANTS
TEMPERATURE DEPENDENCE
VOLUME