Experimental investigation of miscibility conditions of dead and live asphaltenic crude oil–CO2 systems

Golkari, Abdolah; Riazi, Masoud

doi:10.1007/s13202-016-0280-4

Cited by 26 publications

(7 citation statements)

References 58 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…This would have several effects on the sample, such as decrease of density or viscosity, and change in the interfacial tension. Higher pressure and change in the crude oil composition can also affect other phenomena associated with crude oil, for instance wax crystallization 70 and asphaltene behaviour 71 , which can cause further variations in the oil-water interface and alter the coalescence between drops.…”

Section: Pressurementioning

confidence: 99%

Microfluidic tools for studying coalescence of crude oil droplets in produced water

Dudek

Bertheussen

Dumaire

et al. 2018

Chemical Engineering Science

View full text Add to dashboard Cite

The major contaminant targeted during the treatment of the oilfield produced water is dispersed oil.The efficiency of most separation processes highly relies on the size of the droplets, which can be increased through coalescence. Crude oil has a complex and field-dependent composition, which can affect the interfacial properties of the drops, and consequently the merging process in different ways. This study focused on the development of microfluidic techniques for investigating coalescence between crude oil drops. The experiments were performed with six diluted crude oils and three neat oils, the latter in the presence of an oil-soluble surfactant. The composition of the water phase was systematically varied (pH, ionic composition, presence of dissolved components). In general, crude oil droplets coalesced more readily in lower or neutral pH. The addition of dissolved Fluka acids to the water phase had a unique effect on each crude oil, reflecting their composition.What is more, this effect was similar to the presence of water-soluble crude oil components in the aqueous phase. The pressure did not have a significant effect on the coalescence, which was explained by the lack of the lightest components (C1-C4) in the system. In summary, the results revealed several trends, however it was clear that the coalescence highly depended on the oil composition. This underlined the necessity for experimental methods, such as microfluidics, which allow for quick assessment of the stability of crude oil droplets.

show abstract

Section: Pressurementioning

confidence: 99%

Microfluidic tools for studying coalescence of crude oil droplets in produced water

Dudek

Bertheussen

Dumaire

et al. 2018

Chemical Engineering Science

View full text Add to dashboard Cite

show abstract

“…However, CO 2 immiscible flooding is likely to cause early CO 2 breakthrough. Crude oil is considered a colloidal system, the dispersion medium is saturated and aromatic hydrocarbons, and the asphaltenes are in a dispersed phase (Paxton et al, 2002;Golkari and Riazi., 2017;Fakher and Imqam., 2020). When CO 2 is injected into the reservoir, it will dissolve into the crude oil, and its extraction of the light components of the crude oil will lead to changes in the composition of the crude oil system.…”

Section: Introductionmentioning

confidence: 99%

Application of CO2 miscible flooding in ultra-low permeability beach-bar sand reservoir

Yang

Xu²,

Huang

et al. 2022

Front. Earth Sci.

View full text Add to dashboard Cite

The beach-bar sand reservoir of the Sha 4 Member of the Shahejie Formation in the Dongying Sag is the main oil-bearing formation in this area. In recent years, its proven reserves have been getting lower and lower, and the poor petrophysical properties of the reservoir have made water injection development difficult. In turn, it results in a rapid decline in elastic development productivity and low oil recovery. In this study, the experimental evaluation and numerical simulation research on the adaptability of CO2 flooding in beach-bar sand reservoirs are carried out on the basis of fully investigating the successful examples of CO2 flooding conducted by the previous. According to the geological characteristics of the reservoir in the CL area of the Dongying Sag, the reasonable reservoir engineering parameters and surface injection procedures for the CO2 flooding have been formulated. Experiments show that after the completion of water flooding, the recovery factor of the CO2 continuous flooding is 85.64%. It proves that the recovery factor of the CO2 flooding is higher than that of the water flooding. Field tests have shown that CO2 molecules in beach-bar sand reservoirs behave in a supercritical state underground, which is easier to being injected into the reservoir than water. In addition, the displacement distance of the CO2 is obviously larger than that of the water injection development. The gas-oil ratio variation of different flooding types is different, and CO2 flooding can effectively increase the formation energy, and improve the oil recovery and economic benefits of this type of reservoir.

show abstract

“…Asphaltene was first defined by Boussingault (1837) as the "distillation residue of bitumen insoluble in alcohol and soluble in turpentine." This definition was later modified, however, due to an error in the initial part of the definition, which limited asphaltene presence to bitumen; this was later found to be incorrect (Golkari and Riazi 2017;Salleh et al 2019).…”

Section: Introductionmentioning

confidence: 99%

Critical review of asphaltene properties and factors impacting its stability in crude oil

Fakher

Ahdaya

Elturki

et al. 2019

J Petrol Explor Prod Technol

163

111

View full text Add to dashboard Cite

Asphaltene is a component of crude oil that has been reported to cause severe problems during production and transportation of the oil from the reservoir. It is a solid component of the oil that has different structures and molecular makeup which makes it one of the most complex components of the oil. This research provides a detailed review of asphaltene properties, characteristics, and previous studies to construct a guideline to asphaltene and its impact on oil recovery. The research begins with an explanation of the main components of crude oil and their relation to asphaltene. The method by which asphaltene is quantified in the crude oil is then explained. Due to its different structures, asphaltene has been modeled using different models all of which are then discussed. All chemical analysis methods that have been used to characterize and study asphaltene are then mentioned and the most commonly used method is shown. Asphaltene will pass through several phases in the reservoir beginning from its stability phase up to its deposition in the pores, wellbore, and facilities. All these phases are explained, and the reason they may occur is mentioned. Following this, the methods by which asphaltene can damage oil recovery are presented. Asphaltene rheology and flow mechanism in the reservoir are then explained in detail including asphaltene onset pressure determination and significance and the use of micro-and nanofluidics to model asphaltene. Finally, the mathematical models, previous laboratory, and oilfield studies conducted to evaluate asphaltene are discussed. This research will help increase the understanding of asphaltene and provide a guideline to properly study and model asphaltene in future studies.

show abstract

Experimental investigation of miscibility conditions of dead and live asphaltenic crude oil–CO2 systems

Cited by 26 publications

References 58 publications

Microfluidic tools for studying coalescence of crude oil droplets in produced water

Microfluidic tools for studying coalescence of crude oil droplets in produced water

Application of CO2 miscible flooding in ultra-low permeability beach-bar sand reservoir

Critical review of asphaltene properties and factors impacting its stability in crude oil

Contact Info

Product

Resources

About