The stability study of CO 2 foams at high pressure and high temperature

Wang, Yanqing; Zhang, Yang; Liu, Yanmin; Zhang, Liang; Ren, Shaoran; Lu, Jun; Wang, Xiaohui; Fan, Na

doi:10.1016/j.petrol.2017.04.029

Cited by 134 publications

(74 citation statements)

References 58 publications

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“…However, for a CO 2 system, half-life time was much lower compared to the foam generated using air. Wang et al compared the foam stability of the sodium dodecyl surfactant for CO 2 and N 2 gas [40]. They observed that the half-life time of the N 2 foam was up to five times higher compared to the CO 2 foam.…”

Section: Resultsmentioning

confidence: 99%

A Novel Approach to Stabilize Foam Using Fluorinated Surfactants

Kamal

2019

Energies

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Selection of surfactants for enhanced oil recovery and other upstream applications is a challenging task. For enhanced oil recovery applications, a surfactant should be thermally stable, compatible with reservoir brine, and have lower adsorption on reservoir rock, have high foamability and foam stability, and should be economically viable. Foam improves the oil recovery by increasing the viscosity of the displacing fluid and by reducing the capillary forces due to a reduction in interfacial tension. In this work, foamability and foam stability of two different surfactants were evaluated using a dynamic foam analyzer. These surfactants were fluorinated zwitterionic, and hydrocarbon zwitterionic surfactants. The effect of various parameters such as surfactant type and structure, temperature, salinity, and type of injected gas was investigated on foamability and foam stability. The foamability was assessed using the volume of foam produced by injecting a constant volume of gas and foam stability was determined by half-life time. The maximum foam generation was obtained using hydrocarbon zwitterionic surfactant. However, the foam generated using fluorinated zwitterionic surfactant was more stable. A mixture of zwitterionic fluorinated and hydrocarbon fluorinated surfactant showed better foam generation and foam stability. The foam generated using CO2 has less stability compared to the foam generated using air injection. Presence of salts increases the foam stability and foam generation. At high temperature, the foamability of the surfactants increased. However, the foam stability was reduced at high temperature for all type of surfactants. This study helps in optimizing the surfactant formulations consisting of a fluorinated and hydrocarbon zwitterionic surfactant for foam injections.

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Section: Resultsmentioning

confidence: 99%

A Novel Approach to Stabilize Foam Using Fluorinated Surfactants

Kamal

2019

Energies

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“…Therefore, the integrity of foams, used in recovery processes is of utmost importance, which depends on several factors such as the properties of foaming agent, presence of additional liquid or solid phase in the foam structure, rock petrophysical properties and the reservoir condition. [18][19][20].…”

Section: Accepted Manuscriptmentioning

confidence: 99%

Experimental investigation of emulsified oil dispersion on bulk foam stability

Rafati

Oludara

Haddad

et al. 2018

Colloids and Surfaces A: Physicochemical and Engineering Aspect

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Recently aqueous foams have shown promising results to overcome viscous fingering and gravity segregation problems during gas injection process. However, one of the main challenges is the stability of the foams in the presence of oil bank at the front of injected foam. Oil can penetrate into the foam structure in the form of continuous phase or emulsions which might deteriorate lamellae and plateau borders that can result in bubble coalescence and foam rupture. The combination of the surfactant solution, responsible for stabilizing foams, with oil increases the potential for the formation of oil emulsions. In this condition emulsions stability and phase behaviour have the main influence on the bulk foam stability. The objective of this research is to conduct a comprehensive study on the effect of emulsified oil, at different concentrations and salinities on the stability of bulk foams used during oil displacement processes. This was achieved using a foam column test, in which foam is generated and its decay monitored with time. The half-life for each sample was noted and a comparison was made for different cases. Furthermore, changes in the foam bubble sizes and distribution were observed and analysed using an image processing software. A gradual reduction in the half-life

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“…The geological structures used for CO 2 storage include depleted or ongoing oil and gas reservoirs, deep saline aquifers, unmineable coal seams, and offshore hydrate‐bearing sediments 16–20 . At present and near future, oil and gas reservoirs are the most favorable media for CO 2 storage because of the economic potential combined with CO 2 EOR 21,22 . Besides, the storage of CO 2 at oil and gas reservoirs, both depleted and of under development, has the highest confidence in safety as their gas trapping ability has already been proved during the trapping of gas and oil.…”

Section: Introductionmentioning

confidence: 99%

Identification of potential CO₂ leakage pathways and mechanisms in oil reservoirs using fault tree analysis

et al. 2020

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Geological storage of CO 2 technologies has become an important and effective way to reduce the greenhouse gas emissions, especially when it is combined with CO 2 enhanced oil recovery (EOR), which can not only trap CO 2 but also enhance oil recovery. However, the risk of CO 2 leakage has always been a prominent issue. In this paper, the mechanisms and pathways of CO 2 leakage during geological storage in oil reservoirs were analyzed using fault tree analysis (FTR). Besides, monitoring technologies were discussed and deployed in a CO 2 EOR demonstration project. The analysis results showed that the sealing failures of oil producer and CO 2 injector wells, like well cement failure and casing failure, are the main reasons for the CO 2 leakage, which has been observed in the oil field monitoring project. The monitoring results indicated that there is no large-scale CO 2 leakage, while relatively high and abnormal CO 2 concentration in soil gas near some wellbores are observed, which indicates there is some leakage of CO 2 through incomplete cement ring and well casing string. FTR results provide guidelines for monitoring and preventing of CO 2 leakage during geological storage in oil reservoirs. The near-surface monitoring methods, especially the soil gas monitoring technologies, can effectively detect the leakage of CO 2 , and are a proper method for CO 2 leakage monitoring. C 2020

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The stability study of CO 2 foams at high pressure and high temperature

Cited by 134 publications

References 58 publications

A Novel Approach to Stabilize Foam Using Fluorinated Surfactants

A Novel Approach to Stabilize Foam Using Fluorinated Surfactants

Experimental investigation of emulsified oil dispersion on bulk foam stability

Identification of potential CO₂ leakage pathways and mechanisms in oil reservoirs using fault tree analysis

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The stability study of CO 2 foams at high pressure and high temperature

Cited by 134 publications

References 58 publications

A Novel Approach to Stabilize Foam Using Fluorinated Surfactants

A Novel Approach to Stabilize Foam Using Fluorinated Surfactants

Experimental investigation of emulsified oil dispersion on bulk foam stability

Identification of potential CO2 leakage pathways and mechanisms in oil reservoirs using fault tree analysis

Contact Info

Product

Resources

About

Identification of potential CO₂ leakage pathways and mechanisms in oil reservoirs using fault tree analysis