The use of surfactants in enhanced oil recovery: A review of recent advances

https://cyberleninka.org/article/n/1275569.pdf

Status of surfactant EOR technology

The trend of growing interest in alternative source of energy focuses on renewable products worldwide However, the situation of petroleum industries in many countries needs much concern in improving the oil recovery technique Chemical method, especially microemulsion flooding, plays an important role in enhanced oil recovery technique due to its ability to reduce interfacial tension between oil and water to a large extent as well as alter wettability of reservoir rocks Surfactant-based chemical systems have been reported in many academic studies and their technological implementations are potential candidates in enhanced oil recovery activities This paper reviews the role of different types of surfactants in enhanced oil recovery, structure of microemulsion, phase behavior of oil–brine–surfactant/cosurfactant systems with variation of different parameters such as salinity, temperature, pressure and physicochemical properties of microemulsions including solubilization capacity, interfacial tension, viscosity and density under reservoir conditions The enhanced oil productivity by microemulsion flooding with different surfactant/cosurfactant systems has also been discussed in this paper This review introduces a new opening in enhanced oil recovery by microemulsion flooding with some new aspects

/pdf/microemulsions-a-novel-approach-to-enhanced-oil-recovery-a-12dhb7e42y.pdf

Microemulsions: a novel approach to enhanced oil recovery: a review

Alkaline–surfactant–polymer (ASP) flooding is a combination process in which alkali, surfactant, and polymer are injected in the same slug. Because of the synergy of these three components, ASP is the current worldwide focus of research and field trial in chemical enhanced oil recovery (EOR).

This paper is to provide a comprehensive review of the ASP process. The reviewed topics include the following: 

ASP synergy and its EOR mechanisms
Screening criteria
Laboratory work
Numerical simulation work
Summary of pilots and large-scale applications
Project economics
Chemicals used
Water quality
Mobility control requirement
Problems associated with ASP flooding and possible solutions


In addition to the comprehensive review, future developments are also discussed. Data and analyzed results presented in this review will provide the reader with the updated information about ASP and a guide to read relevant papers for those who are new to chemical EOR. The survey data also provide operators with some reference data for their project design and optimization. © 2014 Curtin University of Technology and John Wiley & Sons, Ltd.

A comprehensive review of alkaline–surfactant–polymer (ASP) flooding

The stability study of CO2 foams at high pressure and high temperature

Ammonia as Alkali for Alkaline/Surfactant/Polymer Floods

Oil Recovery and Surfactant Adsorption during CO2-Foam Flooding

This paper (SPE 135357) was accepted for presentation at the SPE Annual Technical Conference and Exhibition, Florence, Italy, 20–22 September 2010, and revised for publication. Original manuscript received for review 2 September 2010. Revised manuscript received for review 27 September 2011. Paper peer approved 10 October 2011. Summary Phase-behavior experiments have identified several surfactant systems that develop high solubilization ratios and low interfacial tension (IFT) with a specific dead paraffinic crude oil at specific salinities. The purpose of this work is to test these surfactant systems with reconstituted live crude. Emulsion-screening tests were performed in sight cells where an equilibrium amount of solution gas is dissolved in the crude at reservoir pressure (1,100 psi). The results indicate that the surfactant is relatively more soluble in the oil phase under these conditions. Thus, a formulated chemical slug for field conditions should contain either less salinity or a more hydrophilic surfactant system than that used in formulations with dead crude. Phase-behavior measurements estimate this offset to be approximately 0.25% less NaCl for the particular live crude in this study. The relevance of this offset is shown by comparing the results of dead-crude corefloods with a live-crude coreflood. A control experiment pressurizing oil with nitrogen at the same condition, 1,100 psi, did not show enhanced relative surfactant solubility in the oil phase.

Effect of Live Crude on Alkaline/Surfactant Polymer Formulations: Implications for Final Formulation Design

Ammonia As Alkali For ASP Floods - Comparison to Sodium Carbonate

The Effect of Live Crude on Alkaline-Surfactant-Polymer Formulations: Implications for Final Formulation Design

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