Comparison Between Micro-Emulsion and Surfactant Solution Flooding Efficiency for Enhanced Oil Recovery in TinFouye Oil Field

2006 ◽  
Author(s):  
M. Bouabboune ◽  
N. Hammouch ◽  
S. Benhadid
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Surfactant Solution ◽  
Oil Field ◽  
Micro Emulsion

scholarly journals Thermal Stability and Compatibility of Surfactants in Presence of Formation Water Salinity under Reservoir Conditions

2020 ◽  
Vol 39 (4) ◽  
pp. 826-830
Author(s):  
Muhammad Khan Memon ◽  
Ubedullah Ansari ◽  
Habib U Zaman Memon
Keyword(s):  
Thermal Stability ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Gas Injection ◽  
Surfactant Solution ◽  
Water Salinity ◽  
Formation Water ◽  
Reservoir Temperature ◽  
Gas Mobility ◽  
Formation Water Salinity

In the surfactant alternating gas injection, the injected surfactant slug is remained several days under reservoir temperature and salinity conditions. As reservoir temperature is always greater than surface temperature. Therefore, thermal stability of selected surfactants use in the oil industry is almost important for achieving their long-term efficiency. The study deals with the screening of individual and blended surfactants for the applications of enhanced oil recovery that control the gas mobility during the surfactant alternating gas injection. The objective is to check the surfactant compatibility in the presence of formation water under reservoir temperature of 90oC and 120oC. The effects of temperature and salinity on used surfactant solutions were investigated. Anionic surfactant Alpha Olefin Sulfonate (AOSC14-16) and Internal Olefin Sulfonate (IOSC15-18) were selected as primary surfactants. Thermal stability test of AOSC14-16 with different formation water salinity was tested at 90oC and 120oC. Experimental result shows that, no precipitation was observed by surfactant AOSC14-16 when tested with different salinity at 90oC and 120oC. Addition of amphoteric surfactant Lauramidopropylamide Oxide (LMDO) with AOSC14-16 improves the stability in the high percentage of salinity at same temperature, whereas, the surfactant blend of IOSC15-18 and Alcohol Aloxy Sulphate (AAS) was resulted unstable. The solubility and chemical stability at high temperature and high salinity condition is improved by the blend of AOSC14-16+LMDO surfactant solution. This blend of surfactant solution will help for generating stable foam for gas mobility control in the methods of chemical Enhanced Oil Recovery (EOR).

Optimization of Surfactant and Polymer for SP Flooding of Zahra Oil

2014 ◽  
Vol 535 ◽  
pp. 701-704 ◽  
Author(s):  
Peng Lv ◽  
Ming Yuan Li ◽  
Mei Qin Lin
Keyword(s):  
Interfacial Tension ◽  
Polymer Solution ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
High Viscosity ◽  
Oil Field ◽  
Interfacial Tensions

Producing ultra-low interfacial tensions and maintaining high viscosity is the most important mechanism relating to SP flooding for enhanced oil recovery. The interfacial tension between surfactant (PJZ-2 and BE)/polymer solution and Zahra oil was evaluated in the work. Based on the evaluatiojn of interfacial tension, the polymer FP6040s/surfactant BE system was selected as the SP flooding system for Zahra oil field.

Omar Hill-300 MW Cogeneration Plant for Enhanced Oil Recovery

1986 ◽  
Author(s):  
Igor S. Ondryas ◽  
Charles O. Myers ◽  
William E. Hauhe
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Oil Field ◽  
Operating Parameters ◽  
Plant Design ◽  
Cogeneration Plant ◽  
Project Schedule ◽  
Commercial Operation ◽  
Major Project ◽  
System Operating

The paper describes a gas turbine based cogeneration plant producing a nominal 300 MWe and 1.8 MM lb/h (0.82 MM kg/h) of 80 percent quality steam for enhanced oil recovery. The plant, which has been in commercial operation since August 18, 1985 is located in the Kern River Oil Field near Bakersfield, California. The plant is owned by the Kern River Cogeneration Company. The paper describes the plant design philosophy as well as the major system operating parameters. The discussion of the overall project schedule highlights the major project milestones.

Post-Combustion Carbon Dioxide Enhanced-Oil-Recovery Development in a Mature Oil Field: Model Calibration Using a Hierarchical Approach

2019 ◽  
Vol 22 (03) ◽  
pp. 0998-1014 ◽  
Author(s):  
Feyi Olalotiti-Lawal ◽  
Tsubasa Onishi ◽  
Hyunmin Kim ◽  
Akhil Datta-Gupta ◽  
Yusuke Fujita ◽  
...  
Keyword(s):  
Carbon Dioxide ◽  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Model Calibration ◽  
Field Model ◽  
Oil Field ◽  
Hierarchical Approach

Using biosurfactant producing bacteria isolated from an Iranian oil field for application in microbial enhanced oil recovery

2016 ◽  
Vol 34 (8) ◽  
pp. 739-746 ◽  
Author(s):  
Amin Daryasafar ◽  
Mohammad Jamialahmadi ◽  
Mahdi Bahari Moghaddam ◽  
Bahman Moslemi
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Oil Field ◽  
Microbial Enhanced Oil Recovery

scholarly journals Characterisation of Indigenous Oil Field Microorganisms for Microbially Enhanced Oil Recovery (MEOR)

2014 ◽  
Vol 86 (9) ◽  
pp. 1485-1485
Author(s):  
M. Krüger ◽  
J. Sitte ◽  
E. Biegel ◽  
H. Alkan ◽  
A. Herold
Keyword(s):  
Enhanced Oil Recovery ◽  
Oil Recovery ◽  
Oil Field ◽  
Microbially Enhanced Oil Recovery
Sign in / Sign up

Export Citation Format

Share Document