Novel Environmentally Benign Hydrogel: Nano-Silica Hybrid Hydrolyzed Polyacrylamide/ Polyethyleneimine Gel System for Conformance Improvement in High Temperature High Salinity Reservoir

2017 ◽  
Author(s):  
Liping Ma ◽  
Shitou Wang ◽  
Yifu Long ◽  
Changqian Zhu ◽  
Hongbin Yang ◽  
...  
Keyword(s):  
High Temperature ◽  
High Salinity ◽  
Environmentally Benign ◽  
Nano Silica ◽  
Hydrolyzed Polyacrylamide ◽  
Silica Hybrid ◽  
Gel System

Gelation Behavior of Polyacrylamide Reinforced with Nano-Silica for Water Shutoff Treatment in Oil Field

2020 ◽  
Vol 307 ◽  
pp. 252-257
Author(s):  
Nurhazwane Abdul Fadil ◽  
Sonny Irawan ◽  
Nur Amelia Mohd Isa ◽  
Siti Rohaida Shafian
Keyword(s):  
Gelation Time ◽  
Silica Content ◽  
Oil Field ◽  
Nano Silica ◽  
Water Shutoff ◽  
Silica Concentration ◽  
Gelation Behavior ◽  
Hydrolyzed Polyacrylamide ◽  
Placement Depth ◽  
Gel System

Polyacrylamide gel system is widely been used in oilfield for water shutoff treatment. Gelation behavior such as proper gelation time provides a basic guideline on gel placement depth in reservoir layers. In this study, the gelation behavior of partially hydrolyzed polyacrylamide crosslinked with chromium(III) acetate (PHPA/Cr3+) reinforced with nano-silica was studied in term of gelation time and gel stability. The gelation time of PHPA/Cr3+ gel could be controlled with the addition of nano-silica where the gel has shown a delay in gelation time at low concentration of nano-silica. At 0.3 wt.% of nano-silica concentration, the gelation time has shown two times delay compared to the original gel system. The gel at the formulations of 0.7 wt.% and 1.0 wt.% nano-silica content remained stable with H code after 24 hours observation.

A Novel Thermoviscosifying Water-Soluble Polymer for Enhancing Oil Recovery from High-Temperature and High-Salinity Oil Reservoirs

2011 ◽  
Vol 306-307 ◽  
pp. 654-657 ◽  
Author(s):  
Yu Wang ◽  
Zhi Yong Lu ◽  
Yu Gui Han ◽  
Yu Jun Feng ◽  
Chong Li Tang
Keyword(s):  
High Temperature ◽  
Oil Recovery ◽  
High Salinity ◽  
Water Soluble ◽  
Oil Reservoirs ◽  
Water Soluble Polymer ◽  
The Poor ◽  
Hydrolyzed Polyacrylamide ◽  
Increasing Temperature ◽  
Enhance Oil Recovery

Polymer flooding represents one of the most efficient processes to enhance oil recovery, but the poor thermostability and salt tolerance of the currently-used partially hydrolyzed polyacrylamide (HPAM) impeded its use in high-temperature and high-salinity oil reservoirs. “Smart” thermoviscosifying polymers (TVPs) may overcome the deficiencies of HPAM. Steady and dynamic rheological behaviors against temperature of a novel TVP were examined in this work in comparison with a commercial HPAM polymer. It was found when increasing temperature, both apparent viscosity and elastic modulus increase for TVP aqueous solution, but decrease for HPAM solution. The results indicate that TVP shows some potential to be used in enhancing oil recovery from high-temperature and high-salinity oil reservoirs.

A Novel Hydroxylpropyl Sulfobetaine Surfactant for High Temperature and High Salinity Reservoirs

2013 ◽  
Author(s):  
Fan Zhang ◽  
Desheng Ma ◽  
Qiang Wang ◽  
Youyi Zhu ◽  
Wenli Luo
Keyword(s):  
High Temperature ◽  
High Salinity
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