Investigating the role of polymer type and dead end pores’ distribution on oil recovery efficiency during ASP flooding

Sedaghat, Mohammadhossein; Hatampour, Amir; Razmi, Rasool

doi:10.1016/j.ejpe.2013.06.003

Cited by 19 publications

(8 citation statements)

References 12 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…This is because of the ability of CTAB to decrease IFT more than SDS. The ASP solution that contains SDS causes ASP/oil IFT of 0.059 dyne/cm; however, the ASP which contains CTAB causes ASP/oil IFT of 0.054 dyne/cm, which is lower than that of SDS and we know that the lower the fluid/oil IFT, the higher the recovery . Thus, in this case, using cationic surfactant in ASP flooding increases the oil recovery and postpones breakthrough more than anionic ones.…”

Section: Resultsmentioning

confidence: 82%

“…Also, in the third scenario, when the brine penetrates polymer slug and reaches alkaline and surfactant, they dissolve easily in each other due to their equal viscosities and consequently the concentration of surfactant and alkaline slugs may become less due to the contact with the pushing slug. So, since a decrease in the concentration of alkaline and surfactant leads to a decrease in recovery efficiency, the ultimate oil recovery becomes less in the third scenario. However, since the ASP and brine have quite different viscosities, this penetration and mixing does not occur seriously in the first scenario.…”

Section: Resultsmentioning

confidence: 99%

See 1 more Smart Citation

Simultaneous/sequential alkaline‐surfactant‐polymer flooding in fractured/non‐fractured carbonate reservoirs

2014

Self Cite

View full text Add to dashboard Cite

Alkaline‐Surfactant‐Polymer flooding is one of the most novel chemical enhanced oil recovery methods in the petroleum industry. This method has attracted interest due to its remarkable advantages. In this work, a series of ASP floods are conducted on fractured/non‐fractured carbonate rocks. The performance of the tests was investigated by various ASP floods consisting of five types of polymers, two surfactants and one common alkaline. ASP was flooded simultaneously and sequentially in four defined scenarios after water flooding. The results showed that although using hydrolysed polymers increases the recovery factor in the fractured medium, sulfonated polymers increase oil recovery even more due to their capability to increase viscosity in saline solutions. Also, since polymers with a higher molecular weight have a larger hydraulic diameter, they increase oil recovery considerably. Moreover, using cationic surfactant improves the efficiency of ASP flooding due to the serious reduction of interfacial tension (IFT) in comparison to using the anionic one. In addition, according to the four scenarios' results, pushing ASP by polymer is much more effective than pushing it with brine. Also, the difference in final oil recovery between simultaneous and sequential ASP floods is more remarkable when ASP is pushed by brine. Thus, choosing a process completely depends on the slug type and the injected volume.

show abstract

Section: Resultsmentioning

confidence: 82%

Section: Resultsmentioning

confidence: 99%

Simultaneous/sequential alkaline‐surfactant‐polymer flooding in fractured/non‐fractured carbonate reservoirs

2014

Self Cite

View full text Add to dashboard Cite

show abstract

“…Polymer application can increase the viscosity of the injection fluid, decreasing the water-oil mobility ratio and water breakthrough, improving the sweep efficiency and thereby increasing the oil recovery factor (Jung et al, 2013;Rellegadla et al, 2017;Sedaghat et al, 2013).…”

Section: Introductionmentioning

confidence: 99%

Polymer viscosifier systems with potential application for enhanced oil recovery: a review

Aguiar

Palermo

Mansur

2021

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

View full text Add to dashboard Cite

Due to the growing demand for oil and the large number of mature oil fields, Enhanced Oil Recovery (EOR) techniques are increasingly used to increase the oil recovery factor. Among the chemical methods, the use of polymers stands out to increase the viscosity of the injection fluid and harmonize the advance of this fluid in the reservoir to provide greater sweep efficiency. Synthetic polymers based on acrylamide are widely used for EOR, with Partially Hydrolyzed Polyacrylamide (PHPA) being used the most. However, this polymer has low stability under harsh reservoir conditions (High Temperature and Salinity – HTHS). In order to improve the sweep efficiency of polymeric fluids under these conditions, Hydrophobically Modified Associative Polymers (HMAPs) and Thermo-Viscosifying Polymers (TVPs) are being developed. HMAPs contain small amounts of hydrophobic groups in their water-soluble polymeric chains, and above the Critical Association Concentration (CAC), form hydrophobic microdomains that increase the viscosity of the polymer solution. TVPs contain blocks or thermosensitive grafts that self-assemble and form microdomains, substantially increasing the solution’s viscosity. The performance of these systems is strongly influenced by the chemical group inserted in their structures, polymer concentration, salinity and temperature, among other factors. Furthermore, the application of nanoparticles is being investigated to improve the performance of injection polymers applied in EOR. In general, these systems have excellent thermal stability and salinity tolerance along with high viscosity, and therefore increase the oil recovery factor. Thus, these systems can be considered promising agents for enhanced oil recovery applications under harsh conditions, such as high salinity and temperature. Moreover, stands out the use of genetic programming and artificial intelligence to estimate important parameters for reservoir engineering, process improvement, and optimize polymer flooding in enhanced oil recovery.

show abstract

“…In this paper, we attempt to gain a conceptual insight into the temperature effects on capillary pressure inside the dead-end pores that to the best of our knowledge hitherto has been very rarely studied. *For correspondence Dead-end pores are generally studied in reference to diffusion within mobile and immobile or dead-end pores [19][20][21][22][23] and in reference to oil recovery through different techniques [24][25][26][27][28][29]. Therefore this paper tries to understand the much overlooked dead-end pores of soil and their influence on the flow characteristics in terms of capillary pressure (as also mentioned by Fatt [30]).…”

Section: Introductionmentioning

confidence: 99%

Conceptual modeling of temperature effects on capillary pressure in dead-end pores

Biswas

Kartha

2019

Sādhanā

View full text Add to dashboard Cite

The effect of temperature on the liquid-gas interface and consequently on the capillary pressure in unsaturated dead-end pores is conceptually modeled in this paper. Trapping of non-wetting fluid (e.g., air) in the dead-end pores impacts the capillary pressure-saturation relationship and affects the continuous flow of wetting fluids. In the dead-end pore, which is assumed to be a simple vertical cylindrical capillary tube with one end closed and the other end open to the liquid body, the dependence of solid-liquid and solid-air interfacial tensions on temperature and its subsequent effects on the contact angles are deduced. A non-linear ordinary differential equation, using the Young-Laplace equation, in terms of a contact-angle-sensitive temperature function is derived and numerically solved using the fourth order Runge-Kutta method. This temperature function is used to obtain the capillary pressure-temperature relationship for a solid-liquid-air capillary system. Two example problems, first a glass-water-air capillary system and second a polytetrafluoroethylene-n-hexadecane-air capillary system, are solved here. A linear decrease in capillary pressure with temperature is observed, suggesting that entrapped air affects capillary pressure in dead-end pores. A similar linear decrease in capillary pressure, consistent with experimental observations, is observed for open-end pores.

show abstract

Investigating the role of polymer type and dead end pores’ distribution on oil recovery efficiency during ASP flooding

Cited by 19 publications

References 12 publications

Simultaneous/sequential alkaline‐surfactant‐polymer flooding in fractured/non‐fractured carbonate reservoirs

Simultaneous/sequential alkaline‐surfactant‐polymer flooding in fractured/non‐fractured carbonate reservoirs

Polymer viscosifier systems with potential application for enhanced oil recovery: a review

Conceptual modeling of temperature effects on capillary pressure in dead-end pores

Contact Info

Product

Resources

About