Improving polymer injectivity at West Coyote Field, California
This paper presents a case history where laboratory and simulation results were used to model a single-well polymer injectivity field test in the West Coyote Field and improve the injectivity in a subsequent field test. The polyacrylamide polymer used in the first test exhibited low injectivity. Laboratory studies were performed to identify the causes of low injectivity and physically model the field test. Laboratory core data and reservoir properties were used in a mathematical model to calculate the polymer injectivity, which closely matched that observed in the field. The low polymer injectivity at West Coyote was due to: formation damage caused by the polymer and low salinity polymer makeup water; and the high resistance factor developed by the polymer. These problems were overcome by: using a lower molecular weight polyacrylamide; preshearing the polymer solution before injection; and increasing the salinity of the polymer makeup water. These improvements resulted in a 50% increase in injectivity during the second polymer injectivity field test at West Coyote.
- Research Organization:
- Chevron Oil Field Research Co.
- OSTI ID:
- 5160651
- Report Number(s):
- CONF-830512-
- Journal Information:
- Soc. Pet. Eng. AIME, Pap.; (United States), Vol. SPE13603; Conference: IEE/APS symposium, Houston, TX, USA, 23 May 1983
- Country of Publication:
- United States
- Language:
- English
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Single-well evaluation program for micellar/polymer recovery, Main and 99 West Pools, West Coyote Field, California
Single-well evaluation program for micellar/polymer recovery, Main and 99 West Pools, West Coyote field, California
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OIL FIELDS
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FORMATION DAMAGE
POLYAMIDES
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ROCK-FLUID INTERACTIONS
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020300* - Petroleum- Drilling & Production