Optimization Chemical Flooding Methods to Enhance Oil Recovery of Strong Heterogeneity, High Temperature and High Salinity Reservoirs - Case Study of Shengli Oilfield

2017 ◽  
Author(s):  
Nu Lu ◽  
Jian Hou ◽  
Yongge Liu ◽  
Lanlei Guo ◽  
Fuqing Yuan ◽  
...  
Keyword(s):  
High Temperature ◽  
Oil Recovery ◽  
High Salinity ◽  
Chemical Flooding ◽  
Shengli Oilfield ◽  
Enhance Oil Recovery

Water-Flooding Fluid Diversion Copolymeric Microsphere Prepared by Inverse Suspension Polymerization

e-Polymers ◽  
2007 ◽  
Vol 7 (1) ◽  
Author(s):  
Huang Zhiyu ◽  
Lu Hongsheng ◽  
Zhang Tailiang
Keyword(s):  
Thermal Stability ◽  
High Temperature ◽  
Oil Recovery ◽  
High Salinity ◽  
Suspension Polymerization ◽  
Oil Reservoirs ◽  
Water Flooding ◽  
Toughness Index ◽  
Inverse Suspension Polymerization ◽  
Enhance Oil Recovery

Abstract In order to enhance oil recovery in high-temperature and high-salinity oil reservoirs, the copolymeric microspheres containing acrylamide (AM), acrylonitrile (AN) and AMPS was synthesized by inverse suspension polymerization. The copolymeric microsphere was very uniform and the size could be changed according to the condition of polymerization. The lab-scale studies showed that the copolymeric microsphere exhibit good salt-tolerance and thermal-stability when immersed in 20×105 mg/L NaCl(or KCl) solution, 7500 mg/L CaCl2 (or MgCl2) solution or 2000 mg/L FeCl3 solution, respectively. The copolymeric microsphere showed satisfactory absorbency rates. The sand-pipes experiments confirmed that the average toughness index was 1.059. It could enhance the oil recovery by about 3% compared with the corresponding irregular copolymeric particle.

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.

scholarly journals Modification of Xanthan Gum for a High-Temperature and High-Salinity Reservoir

Polymers ◽  
2021 ◽  
Vol 13 (23) ◽  
pp. 4212
Author(s):  
Mohamed Said ◽  
Bashirul Haq ◽  
Dhafer Al Shehri ◽  
Mohammad Mizanur Rahman ◽  
Nasiru Salahu Muhammed ◽  
...  
Keyword(s):  
High Temperature ◽  
Oil Recovery ◽  
Xanthan Gum ◽  
Elevated Temperatures ◽  
High Salinity ◽  
Residual Oil ◽  
Core Flooding ◽  
Nacl Solution ◽  
The Core ◽  
Tertiary Oil Recovery

Tertiary oil recovery, commonly known as enhanced oil recovery (EOR), is performed when secondary recovery is no longer economically viable. Polymer flooding is one of the EOR methods that improves the viscosity of injected water and boosts oil recovery. Xanthan gum is a relatively cheap biopolymer and is suitable for oil recovery at limited temperatures and salinities. This work aims to modify xanthan gum to improve its viscosity for high-temperature and high-salinity reservoirs. The xanthan gum was reacted with acrylic acid in the presence of a catalyst in order to form xanthan acrylate. The chemical structure of the xanthan acrylate was verified by FT-IR and NMR analysis. The discovery hybrid rheometer (DHR) confirmed that the viscosity of the modified xanthan gum was improved at elevated temperatures, which was reflected in the core flood experiment. Two core flooding experiments were conducted using six-inch sandstone core plugs and Arabian light crude oil. The first formulation—the xanthan gum with 3% NaCl solution—recovered 14% of the residual oil from the core. In contrast, the modified xanthan gum with 3% NaCl solution recovered about 19% of the residual oil, which was 5% higher than the original xanthan gum. The xanthan gum acrylate is therefore more effective at boosting tertiary oil recovery in the sandstone core.

Enhancing oil recovery from high–temperature and high–salinity reservoirs with smart thermoviscosifying polymers: A laboratory study

Fuel ◽  
2021 ◽  
Vol 288 ◽  
pp. 119777
Author(s):  
Shiwei Li ◽  
Olivier Braun ◽  
Lionel Lauber ◽  
Thierry Leblanc ◽  
Xin Su ◽  
...  
Keyword(s):  
High Temperature ◽  
Laboratory Study ◽  
Oil Recovery ◽  
High Salinity

Application of Biopolymer to Improve Oil Recovery in High Temperature High Salinity Carbonate Reservoirs

2015 ◽  
Author(s):  
Syed Mohamid Raza Quadri ◽  
Li Jiran ◽  
Mohammad Shoaib ◽  
Muhammad Rehan Hashmet ◽  
Ali M. AlSumaiti ◽  
...  
Keyword(s):  
High Temperature ◽  
Oil Recovery ◽  
High Salinity ◽  
Carbonate Reservoirs
Sign in / Sign up

Export Citation Format

Share Document