Oil effect on CO2 foam stabilized by a switchable amine surfactant at high temperature and high salinity

Synergistic Effects between Anionic and Sulfobetaine Surfactants for Stabilization of Foams Tolerant to Crude Oil in Foam Flooding

“…It is well known that the defoaming effects of an oil to the foams can be described by entering coefficient (E), spreading coefficient (S), and bridging coefficient (B) (Chen et al, 2018;Pu et al, 2019;Sun et al, 2015a;Yekeen et al, 2017):…”

“…stable (Chen et al, 2018;Osei-Bonsu et al, 2017;Pu et al, 2019;Sun et al, 2015b;Wang et al, 2016). We have examined the stability of the pseudo-films and related phenomena for our foam systems by observing behaviors of oil droplets released from surfactant solution floating to air/surfactant solution interface.…”

“…On the other hand, foam flooding using conventional commercial surfactants has become another attractive technique and has been paid more attention recently (Amirmoshiri et al, 2018; Bashir et al, 2019; Chen et al, 2018; Da et al, 2018; Hosseini‐Nasab and Zitha, 2017; Hurtado et al, 2018; Jian et al, 2015; Lu et al, 2017; Manan et al, 2015; Pu et al, 2019; Rezvani et al, 2020; Risal et al, 2018; Wang et al, 2009, 2019; Xu et al, 2020; Yang et al, 2017; Yekeen et al, 2017; Zhu et al, 2004). Foam flooding greatly improved the efficiency of gas injection for enhanced oil recovery (EOR), which suffers from problems such as gas segregation, viscous fingering, and gas channeling through high‐permeability zones so that poor sweep efficiencies were usually obtained (Da et al, 2018; Hosseini‐Nasab and Zitha, 2017; Xu et al, 2020; Zhu et al, 2004).…”

“…However, the success of foam flooding depends strongly on foam stability (Amirmoshiri et al, 2018; Jian et al, 2015; Wang et al, 2019; Yang et al, 2017; Yekeen et al, 2017), which is correlated with the liquid drainage in lamellae, surface dilatational elasticity, and strength of the surfactant films (lamellae) (Wang et al, 2009), whereas the foam stability in porous medium is affected by several factors, including temperature, pressure, surfactants used, the presence of oils, electrolytes, polymers, and solid particulate materials (Chen et al, 2018; Hurtado et al, 2018). Many improved foaming systems for foam flooding have been reported in which the protocols for increasing foam stability include addition of nanoparticles (Bashir et al, 2019; Hurtado et al, 2018; Lu et al, 2017; Manan et al, 2015; Rezvani et al, 2020; Risal et al, 2018; Xu et al, 2020; Yang et al, 2017; Yekeen et al, 2017; Zhou et al, 2018), polymers (Bai et al, 2019; Jian et al, 2015; Sun et al, 2015a; Zhu et al, 2004), and alcohols (Chen and Zhao, 2015) and use of mixed surfactants (Hosseini‐Nasab and Zitha, 2017; Wang et al, 2016), branched surfactants (Wang et al, 2009), and fluorine‐containing surfactants (Jian et al, 2015; Wang et al, 2016) etc .…”

“…Among the factors to damage foam stability, the presence of oils is usually detrimental (Amirmoshiri et al, 2018; Chen et al, 2018; Hussain et al, 2019; Pu et al, 2019), which usually behave as excellent defoamers, although positive role of the oils to foam stability has also been reported when they are trapped in foam lamellae as emulsified oil droplets (Pu et al, 2019). As for the relationship between foam stability and oil displacement efficiency, some studies concluded that foam stability was not a necessary requirement in EOR (Pu et al, 2019) and no correlation between bulk foam stability and displacement efficiency was observed (Amirmoshiri et al, 2018), but more studies insisted that foams with high stability are in favor of enhancing oil recovery (Bai et al, 2019; Bashir et al, 2019; Chen and Zhao, 2015; Hosseini‐Nasab and Zitha, 2017; Hurtado et al, 2018; Jian et al, 2015; Lu et al, 2017; Manan et al, 2015; Pu et al, 2019; Rezvani et al, 2020; Risal et al, 2018; Sun et al, 2015; Wang et al, 2009, 2016; Xu et al, 2020; Zhang et al, 2019; Zhou et al, 2018; Zhu et al, 2004).…”