SPE Journal
Volume 15, Number 3, September 2010, pp. 588-597

Summary

Little oil is recovered from fractured oil-wet carbonate rocks by waterflooding. Surfactant treatments are being developed to enhance oil recovery from such formations. This paper investigates the effect of temperature on such surfactant treatments. Anionic and nonionic surfactants have been identified for oil recovery from fractured low-permeability carbonate rocks at high temperatures. For most of the surfactants studied, optimal salinity decreases slightly or remains unchanged with an increase in temperature. Contact angles on initially oil-wet calcite plates decrease on addition of most of the surfactants; the final contact angle decreases with increase in temperature for all the surfactants in the current study. Oil-recovery rate from surfactant solution imbibition increases with temperature for all surfactants. At 90°C, high recovery [approximately 60% original oil in place (OOIP) in 30 days] was obtained for many surfactants at very low surfactant concentrations (< 0.1 wt%) in tight (approximately 15 md) carbonate cores. Surfactant/brine imbibition was found to be a gravity-driven process for these surfactants. Increase in temperature leads to reductions in viscosity and contact angle, which, in turn, increases oil relative permeability, which enhances the oil-recovery rate.

© 2010. Society of Petroleum Engineers

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History

• Original manuscript received: 3 August 2007
• Meeting paper published: 12 November 2007
• Revised manuscript received: 31 October 2009
• Manuscript approved: 5 November 2009
• Published online: 7 April 2010
• Version of record: 22 September 2010