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Screening Criteria for Geologic CO2 Sequestration


Criteria Pressure Gradient: 0.8 psi/ft Temperature Gradient: 1.2°F/100 ft	Criteria Pressure Gradient: 0.433 psi/ft Temperature Gradient: 1.0°F/100 ft

Oil: 5 cP and 37°API
Formation: porosity 16–19%, permeability 34–67 md and water saturation 25–27%
Flood: 13–25’, 10–20 acres, 300–850 psi and 80°F
Initial Conditions: Depleted oil reservoirs
Continuous CO2 Flood (multi-well):
- Large volume (2,000–2,800 ton) over long injection time period (31–41 days)
- Due to injection cessation, depressurization and CO2 expansion during the production period contributes to oil production
Huff ‘n Puff (single well)
- Small volume (184–243 ton) relatively more effective than large volume (1,001 ton)
- Large volume may displace oil from around the well such that when the well is produced much of the mobile oil is no longer around the well.

Mattoon Field, Cole County, Illinois (Cypress Sandstone)
Unit/Well	Sand	CO2	Type	CO2 Injection Duration (days)	Oil Rate Pre-CO2 (bopd)	Oil Rate Post-CO2 (bopd)	Time of Increased Oil Rate (months)
Pinnell Unit
No. 1	A	2,800	Continuous	31	3	60	3
No. 14 Uphoff	A	184	Huff 'n Puff	12	3	6	3+
Sawyer Unit
Unit	E	2,000	Continous	41	9	45	5+
Strong unit
No. 8	D	2,43	Huff 'n Puff	25	0.5	3	4+
No. 6	D	1,001	Huff 'n Puff	25	0.5	0.5	-

Immiscible Liquid CO2 EOR Following Water Displacement

Reference: Beeson and Ortloff, 1959 AIME 216.