Alkali-Surfactant Adsorption and Polymer Injectivity Measurements Using Reservoir Core from a Giant High Temperature and High Salinity Clastic Reservoir to Design an ASP Pilot

2019 ◽  
Author(s):  
Mohammed T. Al-Murayri ◽  
Haya E. Al-Mayyan ◽  
Narjes Al-Mahmeed ◽  
Aarthi Muthuswamy ◽  
Gordon T. Shahin ◽  
...  
Keyword(s):  
High Temperature ◽  
High Salinity ◽  
Surfactant Adsorption ◽  
Clastic Reservoir

Evolution of a Lab-Optimized ASP Formulation for a High Temperature and High Salinity World-Class Clastic Reservoir in the Middle East

2019 ◽  
Author(s):  
Mohammed T. Al-Murayri ◽  
Dawood S. Kamal ◽  
Hadeel F. Baroon ◽  
Gordon T. Shahin ◽  
Shunahshep R. Shukla
Keyword(s):  
High Temperature ◽  
Middle East ◽  
High Salinity ◽  
World Class ◽  
Clastic Reservoir

scholarly journals Adsorption of Ethoxylated Sulfonates on Limestone

1988 ◽  
Vol 5 (1) ◽  
pp. 29-45 ◽  
Author(s):  
M.S. Celik ◽  
A. Shakeel ◽  
H.Y. Al-Yousef ◽  
H.S. Al-Hashim
Keyword(s):  
High Temperature ◽  
High Salinity ◽  
Saudi Arabian ◽  
Surfactant Adsorption ◽  
Precipitation Behavior ◽  
Temperature Conditions

Stastic adsorption experiments have been conducted to investigate the adsorption and precipitation behavior of various ethoxylated sulfonates from Saudi Arabian limestone samples under high-salinity (20%) and high temperature conditions (90°C). The effect of parameters such as salinity, pH, temperature, ethoxylation number, oil and alcohol addition has been investigated. Mechanisms governing surfactant adsorption on limestone are elucidated. A surfactant formulation has been designed to achieve minimum surfactant loss for Saudi Arabian limestone reservoirs.

New Insights into Surfactant Adsorption Estimation During ASP Flooding in Carbonates Under Harsh Conditions Using Surface Complexation Modeling

2021 ◽  
Author(s):  
Ilyas Khurshid ◽  
Emad W. Al-Shalabi ◽  
Imran Afgan
Keyword(s):  
High Temperature ◽  
High Salinity ◽  
Surface Complexation ◽  
Surfactant Adsorption ◽  
Chemical Flooding ◽  
Surface Complexation Modeling ◽  
Asp Flooding ◽  
Repulsive Forces ◽  
Complexation Reactions ◽  
Harsh Conditions

Abstract Several laboratory experiments demonstrated that the use of sodium hydroxide could increase the solution pH and reduce the adsorption of anionic surfactants. However, a better understanding of rock-oil-brine interactions and their effect on surfactant adsorption during alkaline-surfactant-polymer (ASP) flooding is needed for realistic and representative estimations of surfactant adsorption levels. Therefore, this study presents a novel approach to capture these interactions and better predict their effect on surfactant adsorption as well as effluent concentrations of surfactant and various aqueous species. Currently, surface complexation models (SCM) consider rock-brine, oil-brine, and surfactant-brine reactions. In this work, four new surface complexation reactions with intrinsic stability constants that honor oil-surfactant interactions have been proposed for the first time and then validated against experimental data reported in the literature. In addition, we analyzed the effect of various parameters on surface adsorption under harsh conditions of high-temperature and high-salinity using the proposed surface complexation model (SCM). The results showed that the developed surfactant-based SCM is robust and accurate for estimating surfactant adsorption and its concentration in the effluent during chemical floods. The model was validated against two sets of ASP corefloods from the literature including single-phase and two-phase dynamic surfactant adsorption studies. The findings highlighted that oil-surfactant surface complexation reactions are important and should be captured for more representative and accurate estimation of surfactant adsorption during chemical flooding. Moreover, the detail and comprehensive analysis showed that surfactant adsorption increases and its concentration in the effluent decreases with the increase in temperature of the chemical flood, which could be due to the increase in kinetic energy of the species. It was also showed that a decrease in water total salinity decreases the surfactant adsorption on the rock surface, which is related to the increase in the repulsive forces between the adsorbed species. Additionally, with the increase in surfactant concentration in the chemical flood, the effluent surfactant concertation increases, with a slight increase in surfactant adsorption. This slight increase in adsorption can be neglected compared to the injected and produced masses of the surfactant that are proportional. Moreover, the effect of sulfate spiking is significant where the increase in sulfate concentration reduces the surfactant adsorption. Furthermore, it is worth highlighting that the lowest surfactant adsorption levels were achieved through injected water dilution; less than 0.1 mg/g of rock. This is the first study to test a novel formulation of surface complexation modeling considering oil-surfactant effect on surfactant adsorption properties. The proposed framework to estimate surfactant adsorption is conducted for high-temperature and high-salinity reservoir condition. Thus, it could be used in numerical reservoir simulators to estimate oil recovery due to wettability alteration by chemical flooding in carbonates, which will be investigated in our future work. The surfactant adsorption mechanisms during chemical flooding is very case-dependent and hence, the findings of this study cannot be generalized.

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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