Favorable Attributes of Alkaline-Surfactant-Polymer Flooding

Abstract

A laboratory study of the alkaline-surfactant-polymer (ASP) process was conducted. It was found from phase-behavior studies that for a given synthetic surfactant and crude oil containing naphthenic acids, optimal salinity depends only on the ratio of the moles of soap formed from the acids to the moles of synthetic surfactant present. Adsorption of anionic surfactants on carbonate surfaces is reduced substantially by sodium carbonate, but not by sodium hydroxide. The magnitude of the reduction with sodium carbonate decreases with increasing salinity.Particular attention was given to a surfactant blend of a propoxylated sulfate having a slightly branched C 16-17 hydrocarbon chain and an internal olefin sulfonate. In contrast to alkyl/aryl sulfonates previously considered for EOR, alkaline solutions of this blend containing neither alcohol nor oil were single-phase micellar solutions at all salinities up to approximately optimal salinity with representative oils. Phase behavior with a west Texas crude oil at ambient temperature in the absence of alcohol was unusual in that colloidal material, perhaps another microemulsion having a higher soap content, was dispersed in the lower-phase microemulsion. Low interfacial tensions existed with the excess oil phase only when this material was present in sufficient amount in the spinning-drop device. Some birefringence was observed near and above optimal conditions. While this phase behavior is somewhat different from the conventional Winsor phase sequence, overall solubilization of oil and brine for this system was high, leading to low interfacial tensions over a wide salinity range and to excellent oil recovery in both dolomite and silica sandpacks. The sandpack experiments were performed with surfactant concentrations as low as 0.2 wt% and at a salinity well below optimal for the injected surfactant. It was necessary that sufficient polymer be present to provide adequate mobility control, and that salinity be below the value at which phase separation occurred in the polymer/surfactant solution.A 1D simulator was developed to model the process. By calculating transport of soap formed from the crude oil and injected surfactant separately, it showed that injection below optimal salinity was successful because a gradient in local soap-to-surfactant ratio developed during the process. This gradient increases robustness of the process in a manner similar to that of a salinity gradient in a conventional surfactant process. Predictions of the simulator were in excellent agreement with the sandpack results.

Review of surfactant-assisted chemical enhanced oil recovery for carbonate reservoirs: challenges and future perspectives

“…As stated earlier, surfactant plays a pivotal role in microemulsion formation, and among all surfactants, anionic surfactants are the most well-known and widely used surfactants in oil recovery (Liu et al 2008). The domain of cationic surfactant-based microemulsion methods is still less explored, and this could be a future area of research for scientists targeting enhanced oil recovery from carbonate reservoirs.…”

“…ASP for carbonate reservoirs received little focus until the last few years. Reasons include: the high-divalent-ion environment of the carbonate reservoirs leads to the formation of calcium and magnesium sulfonates with the typical commercially available surfactants (alkyl/aryl sulfonates) that either precipitate or partition out into the oil phase (Liu et al 2008). An exception to this observation was reported in the early works of Adams and Schievelbein 1987, who demonstrated that oil could be displaced from a carbonate reservoir using a mixture of petroleum sulfonates and alkyl ether sulfates or alkyl/aryl ether sulfates.…”

Measurement of Streaming Potential in Downhole Application: An Insight for Enhanced Oil Recovery Monitoring

“…(2008) has proved that soap-to-surfactant ratio is important, which has significant contribution in order to understand the ASP process [47]. Besides, formation wettability can be altered with the presence of alkali to become more oil-wet or water-wet.…”

Phase behavior and interfacial tension evaluation of a newly designed surfactant on heavy oil displacement efficiency; effects of salinity, wettability, and capillary pressure

“…Liu et al [8] have also reported that the mixture of the surfactants would be able to tolerate hash reservoirs condition with high salinity concentration compared to single surfactant component solution. According to their results considering chemicals with intermediate groups connecting the hydrophobic parts to the hydrophilic sections raises the droplet stability in the micro-emulsion state and provides more stable interfaces.…”