A laboratory investigation of the optimum CO/sub 2/ slug size required for CO/sub 2/ flooding

Conference · Wed Feb 01 04:00:00 EST 1984 · Am. Soc. Mech. Eng., (Pap.); (United States)

OSTI ID:6868310

Omole, O; Osoba, J S

The optimum CO/sub 2/ bank size required during CO/sub 2/ flooding was studied in linear horizontal consolidated sandstone cores. Crude oils were displaced from the cores by different CO/sub 2/ slug sizes propelled with brine at pressures above the CO/sub 2/ - crude oil miscibility pressures of the oils. Two natural crude oils of 34/sup 0/ and 44/sup 0/ API gravity, two 2 in. X 2 in. 15 foot long and a 5 foot long horizontal consolidated sandstone cores were used for the investigation. Studies were conducted at 110/sup 0/ and at 120/sup 0/ F. A 0.3 HPV of CO/sub 2/ slug was found to be an optimum bank size required for flooding in the horizontal cores using water as the slug propellant. The total oil recoveries were lower for tests conducted at 120/sup 0/ F than for those conducted at 110/sup 0/ F.

• Research Organization: Department of Petroleum Engineering, Texas A and M University
• OSTI ID: 6868310
• Report Number(s): CONF-840201-
• Conference Information: Journal Name: Am. Soc. Mech. Eng., (Pap.); (United States) Journal Volume: 84-PET-16
• Country of Publication: United States
• Language: English

Related Subjects

02 PETROLEUM
020300* -- Petroleum-- Drilling & Production
BENCH-SCALE EXPERIMENTS
CARBON DIOXIDE INJECTION
DRILL CORES
ENERGY SOURCES
ENHANCED RECOVERY
FLOW RATE
FLUID FLOW
FLUID INJECTION
FOSSIL FUELS
FUELS
MATERIALS TESTING
MEDIUM TEMPERATURE
MISCIBLE-PHASE DISPLACEMENT
OIL WELLS
OPTIMIZATION
PETROLEUM
RECOVERY
ROCKS
SANDSTONES
SEDIMENTARY ROCKS
STIMULATION
TEMPERATURE DEPENDENCE
TESTING
VISCOSITY
WELL STIMULATION
WELLS