Recent advances in ASP flooding and the implementation of nanoparticles to enhance oil recovery: a short review

Arsad, Agus; Al-Jaber, Hasanain A.; Junin, Radzuan; Bandyopadhyay, Sulalit; Abdulmunem, Abdulmunem R.; Oseh, Jeffrey O.; Agi, Augustine; Abdurrahman, Muslim; Kadir, Evizal Abdul; Rahim, Sharul Kamal Abdul

doi:10.1080/10916466.2021.1980013

Cited by 5 publications

(2 citation statements)

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“…Efforts to enhance the efficiency and cost-effectiveness of ASP flooding have faced many challenges since its application as a tertiary process. According to Arsad et al [ 14 ], achieving a higher incremental recovery requires that the oil–water interfacial tension reach a level of 10 −3 mN/m, which is not easily attainable by only selecting one kind and concentration of the applied surfactant. Arsad et al [ 14 ] added increasing the alkali content can significantly reduce the IFT, but this can potentially lead to some issues, such as decreasing the viscosity of the ASP stream.…”

Section: Introductionmentioning

confidence: 99%

“…According to Arsad et al [ 14 ], achieving a higher incremental recovery requires that the oil–water interfacial tension reach a level of 10 −3 mN/m, which is not easily attainable by only selecting one kind and concentration of the applied surfactant. Arsad et al [ 14 ] added increasing the alkali content can significantly reduce the IFT, but this can potentially lead to some issues, such as decreasing the viscosity of the ASP stream. To address this concern, adding additional polymer to compensate for the viscosity reduction is recommended.…”

Section: Introductionmentioning

confidence: 99%

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Relation between Conventional and Starch-Assisted ASP Injection and Impact of Crystallinity on Flood Formation

Al-Jaber,

Arsad,

Bandyopadhyay

et al. 2023

Molecules

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Alkaline–surfactant–polymer (ASP) flooding, a recognized method for oil recovery, encounters limited use due to its expense. In addition, ASP’s best composition and injection sequence still remains uncertain today. This study explores conventional ASP flooding using PT SPR Langgak’s special surfactants, simulating Langgak oilfield conditions in Sumatra, Indonesia. By comparing the outcomes of this flooding technique with that of starch-assisted ASP performed in another study, the benefits of adding starch nanoparticles to flooding are evident. Nano-starch ASP increased oil recovery by 18.37%, 10.76%, and 10.37% for the three configurations investigated in this study. Water flooding preceded ASP flooding, and flooding operations were carried out at 60 °C. This study employed sodium hydroxide (NaOH), sodium carbonate (Na2CO3), and specialized surfactants from PT SPR. The adopted polymer is solely hydrolyzed polyacrylamide (HPAM) at 2000 ppm. Starch nanoparticles underwent comprehensive characterization and focused more on charge stability. Purple yam nanoparticles (PYNPs) exhibited remarkable stability at −36.33 mV, unlike cassava starch nanoparticles (CSNPs’) at −10.68 mV and HPAM’s at −27.13 mV. Surface properties affect interactions with fluids and rocks. Crystallinity, a crucial characterization, was assessed using Origin software 2019b. CSNPs showed 24.15% crystallinity, surpassing PYNPs’ 20.68%. Higher crystallinity benefits CSNPs’ thermal stability. The amorphous behavior found in PYNPs makes them less suitable if applied in harsh reservoirs. This research correlated with prior findings, reinforcing starch nanoparticles’ role in enhancing oil recovery. In summary, this study highlighted conventional ASP flooding using HPAM as the sole polymer and compared it with three formations that used two starch nanoparticles included with HPAM, assessing their impact on charge stability, crystallinity, and recovery rate to emphasize their importance in the oil recovery industry. Starch nanoparticles’ benefits and limitations guided further investigation in this study.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%