Green water flooding of fractured and heterogeneous oil reservoirs at high salinity and high temperature

2018 ◽  
Vol 3 (6) ◽  
pp. 386-391
Author(s):  
Omar Chaalal
Keyword(s):  
High Temperature ◽  
High Salinity ◽  
Oil Reservoirs ◽  
Water Flooding ◽  
Green Water

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 Polymer-Phenolic Prepolymer Based Blocking System for High-Temperature and High-Salinity Oil Reservoirs

2020 ◽  
Vol 57 (6) ◽  
pp. 534-539
Author(s):  
Yang Wang ◽  
Jian Wang ◽  
Fenfen Du ◽  
Hongwei Fan ◽  
Xiaoxiang Wang ◽  
...  
Keyword(s):  
High Temperature ◽  
High Salinity ◽  
Oil Reservoirs

A New Process for Manufacturing and Stabilizing High-Performance EOR Surfactants at Low Cost for High-Temperature, High-Salinity Oil Reservoirs

2010 ◽  
Author(s):  
Stephanie Adkins ◽  
Pathma Jith Liyanage ◽  
Gayani W.P. Pinnawala Arachchilage ◽  
Thilini Mudiyanselage ◽  
Upali Weerasooriya ◽  
...  
Keyword(s):  
High Temperature ◽  
High Performance ◽  
High Salinity ◽  
Low Cost ◽  
Oil Reservoirs ◽  
New Process

scholarly journals NEW AQUEOUS POLYMER FOR HIGH-TEMPERATURE RESERVOIRS

2018 ◽  
Vol 15 (30) ◽  
pp. 380-386
Author(s):  
Y. V. SAVINYKH ◽  
L. D. LANG
Keyword(s):  
High Temperature ◽  
Oil Recovery ◽  
High Salinity ◽  
Sea Water ◽  
Polymer Flooding ◽  
Water Soluble ◽  
Water Flooding ◽  
Polymer Gel ◽  
Sweep Efficiency ◽  
Water Soluble Polymer

Polymer flooding is technologically simple and highly effective method of enhanced oil recovery. The method is based on adding a small amount of polymer in conventional water flooding of oil reservoirs. The increase in viscosity and the reduction of the mobility of injected water are to equalize the displacement front by slowing the moving of water in the highly permeable zones and restricting the formation of water finger. These factors help to increase the sweep efficiency and oil-water displacement efficiency during flooding. Polymer flooding has been used successfully in clastic and carbonate reservoirs, as well as in low-permeability reservoirs such as a fractured basement. However, most of the current polymer gel used for control water flows are decayed by a high content of ions Ca2+ and Mg2+ in formation water or in injected water. Similarly, polymer gels lose their stability at high reservoir temperature (above 70°C). Developing water-soluble polymer, which does not change their rheological properties under high salinity and high temperature (over 100°C), is very important when producing offshore, where sea water is commonly used for flooding (high salinity of 30-40 g/L).

scholarly journals Development of enhanced nanocomposite preformed particle gels for conformance control in high-temperature and high-salinity oil reservoirs

2014 ◽  
Vol 46 (5) ◽  
pp. 277-284 ◽  
Author(s):  
Cecilia Durán-Valencia ◽  
Baojun Bai ◽  
Horacio Reyes ◽  
Romina Fajardo-López ◽  
Fernando Barragán-Aroche ◽  
...  
Keyword(s):  
High Temperature ◽  
High Salinity ◽  
Oil Reservoirs ◽  
Conformance Control ◽  
Preformed Particle Gels

scholarly journals Laboratory Study on the Potential EOR Use of HPAM/VES Hybrid in High-Temperature and High-Salinity Oil Reservoirs

2013 ◽  
Vol 2013 ◽  
pp. 1-8 ◽  
Author(s):  
Dingwei Zhu ◽  
Jichao Zhang ◽  
Yugui Han ◽  
Hongyan Wang ◽  
Yujun Feng
Keyword(s):  
Thermal Stability ◽  
High Temperature ◽  
Salinity Tolerance ◽  
Oil Recovery ◽  
High Salinity ◽  
Oil Reservoirs ◽  
Mechanical Degradation ◽  
Core Flooding ◽  
Reservoir Conditions ◽  
Viscoelastic Surfactant

Polymer flooding represents one of the most efficient processes to enhance oil recovery, and partially hydrolyzed polyacrylamide (HPAM) is a widely used oil-displacement agent, but its poor thermal stability, salt tolerance, and mechanical degradation impeded its use in high-temperature and high-salinity oil reservoirs. In this work, a novel viscoelastic surfactant, erucyl dimethyl amidobetaine (EDAB), with improved thermal stability and salinity tolerance, was complexed with HPAM to overcome the deficiencies of HPAM. The HPAM/EDAB hybrid samples were studied in comparison with HPAM and EDAB in synthetic brine regarding their rheological behaviors and core flooding experiments under simulated high-temperature and high-salinity oil reservoir conditions (T: 85°C; total dissolved solids: 32,868 mg/L; [Ca2+] + [Mg2+]: 873 mg/L). It was found that the HPAM/EDAB hybrids exhibited much better heat- and salinity-tolerance and long-term thermal stability than HPAM. Core flooding tests showed that the oil recovery factors of HPAM/EDAB hybrids are between those of HPAM and EDAB. These results are attributed to the synergistic effect between HPAM and EDAB in the hybrid.

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