Wettability alteration of carbonate rocks via magnetic fields application

Hosseini, Hashem; Apourvari, Saeid Norouzi; Schaffie, Mahin

doi:10.1016/j.petrol.2018.08.022

Cited by 14 publications

(8 citation statements)

References 33 publications

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“…Moreover, carbonate rock samples being obtained from the outcrop of Asmari formation were used as main rock samples for measuring contact angles. Their mineral composition detected by X-ray fluorescence showed that CaO held the highest amount (35.8 w/w %) among others [4]. Additionally, calcium carbonate powder was applied as the carbonate rock for thermogravimetric analysis (TGA) measurements.…”

Section: Methodsmentioning

confidence: 99%

“…Finally, the samples were stored in an oven for 2 h at 60 °C. Consequently, the aging process was instantly conducted to diminish the contamination [4]. All samples including carbonate rocks and powder were soaked in distilled water for 24 h and dried in the oven for 24 h at 40 °C.…”

Section: Rock Samples Preparationmentioning

confidence: 99%

“…After the aging process, samples were kept in the oven at 50 °C for drying. The whole procedure of this section was performed based on the literature [4].…”

Section: Rock Samples Preparationmentioning

confidence: 99%

“…Only 10 to 30 percent of the oil in those reservoirs is recovered because they are normally oil-wet or intermediate-wet, which captured oil in their matrix blocks [2,3]. Therefore, enhanced oil recovery (EOR) methods seem to be important for these reservoirs [4]. Waterflooding might be an inefficient method to be employed in oil-wet fractured reservoirs owing to the fact that the injected water cannot easily enter the porous matrices, and as a result, it cannot displace the oil in place [5][6][7][8].…”

Section: Introductionmentioning

confidence: 99%

“…Waterflooding might be an inefficient method to be employed in oil-wet fractured reservoirs owing to the fact that the injected water cannot easily enter the porous matrices, and as a result, it cannot displace the oil in place [5][6][7][8]. Therefore, other efficient mechanisms, for say wettability alteration, are expected to enhance oil recovery in those reservoirs [4,9,10]. Different processes of wettability alteration for EOR have been studied, including surfactant flooding [11][12][13][14][15], surfactant-alkaline flooding [16][17][18][19], microemulsion flooding [20], nanoparticle (NP) applications [21][22][23][24][25], hot urea solutions B Saeid Norouzi-Apourvari snorouzi@uk.ac.ir 1 Department of Petroleum Engineering, Shahid Bahonar University of Kerman, Kerman, Iran [26], and low-salinity waterflooding [27][28][29].…”

Section: Introductionmentioning

confidence: 99%

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Insight into the Synergic Effect of Ultrasonic Waves, SDS Surfactant, and Silica Nanoparticles on Wettability Alteration of Carbonate Rocks

et al. 2021

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The impact of ultrasonic radiation, as an emerging enhanced oil recovery technique, on reservoir fluid properties is of great importance in petroleum engineering. Although the effect of sonication on fluid properties has been widely investigated, the wettability alteration of carbonate rocks via different solutions under ultrasonic radiation has not been considered. In this study, the synergic impact of ultrasonic radiation on the wettability alteration of carbonate rocks was studied by using distilled water, seawater, SDS surfactant, silica nanoparticles, and SDS surfactant-silica nanoparticles solutions. Variance analysis showed that all parameters under ultrasonic radiation, including types of water, surfactant solution, nanoparticles, sonication time, and temperature, were meaningful and had influences on the wettability alteration. The contact angle decreased notably by raising the temperature and sonication time. Ultrasonic waves improved the elimination of chemisorbed fatty acids on the surface, and this could be one of the mechanisms of wettability alteration by the ultrasonic application.

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Section: Methodsmentioning

confidence: 99%

Section: Rock Samples Preparationmentioning

confidence: 99%

“…After the aging process, samples were kept in the oven at 50 °C for drying. The whole procedure of this section was performed based on the literature [4].…”

Section: Rock Samples Preparationmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Insight into the Synergic Effect of Ultrasonic Waves, SDS Surfactant, and Silica Nanoparticles on Wettability Alteration of Carbonate Rocks

et al. 2021

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Effects of static magnetic field on the surface tension of surfactant solutions

Chibowski

Terpiłowski

Hołysz

et al. 2023

J Surfact & Detergents

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The magnetic field (MF) effects resulting from water or solution treatments are still of significant interest. However, a relatively small number of papers have been published dealing with the pure surfactant solutions alone. On the other hand, surfactants are applied in many industrial processes as well as in everyday life and are also present in different waste waters. Therefore, it seemed interesting to investigate whether some effects would appear after the MF treatment of pure aqueous surfactant solutions. In the earlier published papers after MF action the changes in water evaporation rate and the surface tension were found for both the cationic dodecyltrimethylammonium bromide (DTAB) and anionic sodium dodecyl sulfate (SDS) solutions. The gradient MF originated from three connected ring magnets inside which the solutions were placed. The objective of this paper is to study whether using the same magnets but in a different position the effects of the MF are observed. The given surfactant solution in a closed vessel was placed in an uniform MF when the magnets were in the “lying” position. The investigated solutions on the magnet surface remained for 24 h. In this paper, despite SDS and DTAB also the cationic hexadecyltrimethylammonium bromide (CTAB) and nonionic Triton X‐100 solutions were applied. It appeared that in the uniform MF the surface tension of cationic and anionic surfactant solutions changes. However, larger changes were observed in the gradient MF. Generally, the changes of surface tension depend on the surfactant kind and its concentration. Stronger MF influence was found for the cationic surfactant and almost no changes were observed for nonionic Triton X‐100.

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