Alkaline-Surfactant-Polymer Flooding for Heavy Oil Recovery from Strongly Water Wet Cores Using Sodium Hydroxide, Lauryl Sulphate, Shell Enordet 0242, Gum Arabic and Xanthan Gum

2015 ◽  
Author(s):  
Ujuanbi Solomon ◽  
Taiwo Oluwaseun ◽  
Olafuyi Olalekan
Keyword(s):  
Sodium Hydroxide ◽  
Oil Recovery ◽  
Heavy Oil ◽  
Xanthan Gum ◽  
Gum Arabic ◽  
Polymer Flooding ◽  
Heavy Oil Recovery ◽  
Alkaline Surfactant Polymer

scholarly journals Effect of Hydrophobic and Hydrophilic Metal Oxide Nanoparticles on the Performance of Xanthan Gum Solutions for Heavy Oil Recovery

Nanomaterials ◽  
2019 ◽  
Vol 9 (1) ◽  
pp. 94 ◽  
Author(s):  
Laura Corredor ◽  
Maen Husein ◽  
Brij Maini
Keyword(s):  
Metal Oxide ◽  
Oil Recovery ◽  
Heavy Oil ◽  
Xanthan Gum ◽  
Colloidal Stability ◽  
Metal Oxide Nanoparticles ◽  
Oxide Nanoparticles ◽  
Heavy Oil Recovery ◽  
Tio2 Nps ◽  
Ζ Potential

Recent studies revealed higher polymer flooding performance upon adding metal oxide nanoparticles (NPs) to acrylamide-based polymers during heavy oil recovery. The current study considers the effect of TiO2, Al2O3, in-situ prepared Fe(OH)3 and surface-modified SiO2 NPs on the performance of xanthan gum (XG) solutions to enhance heavy oil recovery. Surface modification of the SiO2 NPs was achieved by chemical grafting with 3-(methacryloyloxy)propyl]trimethoxysilane (MPS) and octyltriethoxysilane (OTES). The nanopolymer sols were characterized by their rheological properties and ζ-potential measurements. The efficiency of the nanopolymer sols in displacing oil was assessed using a linear sand-pack at 25 °C and two salinities (0.3 wt % and 1.0 wt % NaCl). The ζ-potential measurements showed that the NP dispersions in deionized (DI) water are unstable, but their colloidal stability improved in presence of XG. The addition of unmodified and modified SiO2 NPs increased the viscosity of the XG solution at all salinities. However, the high XG adsorption onto the surface of Fe(OH)3, Al2O3, and TiO2 NPs reduced the viscosity of the XG solution. Also, the NPs increased the cumulative oil recovery between 3% and 9%, and between 1% and 5% at 0 wt % and 0.3 wt % NaCl, respectively. At 1.0 wt % NaCl, the NPs reduced oil recovery by XG solution between 5% and 12%, except for Fe(OH)3 and TiO2 NPs. These NPs increased the oil recovery between 2% and 3% by virtue of reduced polymer adsorption caused by the alkalinity of the Fe(OH)3 and TiO2 nanopolymer sols.

Enhancing Heavy-Oil-Recovery Efficiency by Combining Low-Salinity-Water and Polymer Flooding

SPE Journal ◽  
2020 ◽  
pp. 1-17
Author(s):  
Yang Zhao ◽  
Shize Yin ◽  
Randall S. Seright ◽  
Samson Ning ◽  
Yin Zhang ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
High Salinity ◽  
Polymer Flooding ◽  
Heavy Oil Recovery ◽  
Sweep Efficiency ◽  
Low Salinity ◽  
Low Salinity Water ◽  
Salinity Water ◽  
Increased Oil Recovery

Summary Combining low-salinity-water (LSW) and polymer flooding was proposed to unlock the tremendous heavy-oil resources on the Alaska North Slope (ANS). The synergy of LSW and polymer flooding was demonstrated through coreflooding experiments at various conditions. The results indicate that the high-salinity polymer (HSP) (salinity = 27,500 ppm) requires nearly two-thirds more polymer than the low-salinity polymer (LSP) (salinity = 2,500 ppm) to achieve the target viscosity at the condition of this study. Additional oil was recovered from LSW flooding after extensive high-salinity-water (HSW) flooding [3 to 9% of original oil in place (OOIP)]. LSW flooding performed in secondary mode achieved higher recovery than that in tertiary mode. Also, the occurrence of water breakthrough can be delayed in the LSW flooding compared with the HSW flooding. Strikingly, after extensive LSW flooding and HSP flooding, incremental oil recovery (approximately 8% of OOIP) was still achieved by LSP flooding with the same viscosity as the HSP. The pH increase of the effluent during LSW/LSP flooding was significantly greater than that during HSW/HSP flooding, indicating the presence of the low-salinity effect (LSE). The residual-oil-saturation (Sor) reduction induced by the LSE in the area unswept during the LSW flooding (mainly smaller pores) would contribute to the increased oil recovery. LSP flooding performed directly after waterflooding recovered more incremental oil (approximately 10% of OOIP) compared with HSP flooding performed in the same scheme. Apart from the improved sweep efficiency by polymer, the low-salinity-induced Sor reduction also would contribute to the increased oil recovery by the LSP. A nearly 2-year pilot test in the Milne Point Field on the ANS has shown impressive success of the proposed hybrid enhanced-oil-recovery (EOR) process: water-cut reduction (70 to less than 15%), increasing oil rate, and no polymer breakthrough so far. This work has demonstrated the remarkable economical and technical benefits of combining LSW and polymer flooding in enhancing heavy-oil recovery.

A comparative study of the mechanism and performance of surfactant- and alkali-polymer flooding in heavy-oil recovery

2020 ◽  
Vol 219 ◽  
pp. 115603 ◽  
Author(s):  
MingChen Ding ◽  
Yefei Wang ◽  
Fuqing Yuan ◽  
Hailong Zhao ◽  
Zongyang Li
Keyword(s):  
Comparative Study ◽  
Oil Recovery ◽  
Heavy Oil ◽  
Polymer Flooding ◽  
Heavy Oil Recovery ◽  
And Performance

Effect of Nanoclay on Heavy Oil Recovery During Polymer Flooding

2015 ◽  
Vol 33 (9) ◽  
pp. 999-1007 ◽  
Author(s):  
G. Cheraghian ◽  
S. S. Khalilinezhad
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Polymer Flooding ◽  
Heavy Oil Recovery

Dominant Scaling Groups of Polymer Flooding for Enhanced Heavy Oil Recovery

2012 ◽  
Vol 52 (2) ◽  
pp. 911-921 ◽  
Author(s):  
Ziqiang Guo ◽  
Mingzhe Dong ◽  
Zhangxin Chen ◽  
Jun Yao
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Polymer Flooding ◽  
Heavy Oil Recovery
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