Wetting behavior of selected crude oil/brine/rock systems. Topical report, March 1, 1995--March 31, 1996

• Main Authors: Zhou, X., Morrow, N.R., Ma, S.
• Other Authors: United States. Office of the Assistant Secretary for Fossil Energy.
• Format: Report
• Language: English
• Published: University of Wyoming Research Corporation. Western Research Institute. 1996
• Subjects: 02 Petroleum; Brines; Waterflooding; Water Saturation; Age Dependence; Progress Report; Petroleum; Enhanced Recovery; Experimental Data; Wettability; Sandstones; Rock-Fluid Interactions; Reservoir Rock; Prudhoe Bay
• Online Access: https://doi.org/10.2172/568991; https://digital.library.unt.edu/ark:/67531/metadc692995/

Previous studies of crude oil/brine/rock (COBR) and related ensembles showed that wettability and its effect on oil recovery depend on numerous complex interactions. In the present work, the wettability of COBR ensembles prepared using Prudhoe Bay crude oil, a synthetic formation brine, and Berea Sandstone was varied by systematic change in initial water saturation and length of aging time at reservoir temperature (88 C). All displacement tests were run at ambient temperature. Various degrees of water wetness were achieved and quantified by a modified Amott wettability index to water, the relative pseudo work of imbibition, and a newly defined apparent advancing dynamic contact angle. Pairs of spontaneous imbibition (oil recovery by spontaneous imbibition of water) and waterflood (oil recovery vs. pore volumes of water injected) curves were measured for each of the induced wetting states. Several trends were observed. Imbibition rate, and hence water wetness, decreased with increase in aging time and with decrease in initial water saturation. Breakthrough recoveries and final oil recovery by waterflooding increased with decrease in water wetness. Correlations between water wetness and oil recovery by waterflooding and spontaneous imbibition are presented.