Wettability Alteration of Carbonate Rock by Chelating Agents and Viscoelastic Surfactants: Synergetic Impact

Deng, Xiao; Patil, Shirish; Kamal, Muhammad Shahzad; Sultan, Abdullah S.; Saikia, Tinku

doi:10.1021/acs.energyfuels.2c01003

Cited by 11 publications

(6 citation statements)

References 41 publications

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“…From his study, he concluded that viscoelastic surfactant in the ideal formulation resulted in a change in wettability by varying contact angle from 163°to 64.2°. [12] According to Kume et al, the CMC of mixes of anionic/cationic binary surfactants is lower than individual surfactants. [13] The strongest interaction occurs between binary surfactant mixes, according to Li et al, who employed a mixture of anionic and cationic surfactant.…”

Section: Introductionmentioning

confidence: 99%

Synthesis and Evaluation of Mesoporous Silica Nanoparticle and its Application in Chemical Enhanced oil Recovery

et al. 2023

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A significant quantity of hydrocarbons remains in the reservoir after production using primary and secondary techniques. Traditional recovery techniques produce about 33 % of the original oil in place. However, the utilization of chemicals such as surfactants and polymers facilitate the additional recovery of one‐third of this oil. Researchers are currently aiming at mixing surfactant and nanoparticles for their potential applications in petroleum industry. In this work, authors claimed to be the first to study usage of synthesized Mesoporous Silica Nanoparticles (MSN) with Sodium Dodecyl Sulphate (SDS) surfactant to understand its applicability in Chemical Enhanced Oil Recovery through evaluation of the surface tension & Interfacial tension, surfactant adsorption, contact angle, and core flooding experiments. Surface tension studies revealed a synergistic interaction between MSN and anionic surfactant molecules. With the introduction of 2500 ppm of anionic surfactant, the surface tension of deionized water reduces to 34.5 mN/m from 72.4 mN/m. The surface tension of the mixture was further lowered by ∼9.8 % with the addition of 300 ppm MSN. The Interfacial Tension results also showed the same trend. When 300 ppm of MSN was introduced, then IFT values decreases from 8.13 mN/m to 3.91 mN/m at 2500 ppm of anionic surfactant. Contact angle measurements after MSN injection went from 77.98° for SDS (2500 ppm) to 73.36°, 66.54°, and 41.95° for 100, 200, and 300 ppm of MSN, respectively. This demonstrates that the shift toward water‐wet behavior increased along with the MSN concentration. Additionally, adding 300 ppm of MSN lowered surfactant adsorption by ∼80 % at a surfactant concentration of 2500 ppm. Up to 72.27 % of the OOIP could be recovered using the chemical slug made of SDS surfactant, polymer, and MSN. The research data suggests that the MSN can increase the effectiveness of the chemical injection approach, which can be used to recover more oil.

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Section: Introductionmentioning

confidence: 99%

Synthesis and Evaluation of Mesoporous Silica Nanoparticle and its Application in Chemical Enhanced oil Recovery

et al. 2023

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“…A few studies have been conducted using chelating agents, viscoelastic, and Gemini surfactants to alter the wettability of carbonate formations. , Jafarbeigi et al investigated the effect of reducing the interfacial tension on altering the wettability of carbonate formations. The use of nanofluids increased the hydrocarbon recovery by 26%.…”

Section: Introductionmentioning

confidence: 99%

Wettability Alteration of Berea Sandstone for Gas Condensate Applications

Alajmei

2023

ACS Omega

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Gas condensate reservoirs can suffer significant decreases in production due to the buildup of liquid in the vicinity of the wellbore, which occurs when the bottom-hole flowing pressure drops below the dew point pressure. Consequently, the generated liquid hydrocarbons can hinder the movement of the produced gas by adhering to the surfaces, thereby creating a condensate bank. One potential method for mitigating the issue of condensate banking involves the injection of chemical treatment and the alteration of wettability from a liquid-wet state to an intermediate gas-wet state. This study conducted an experimental investigation of the impact of fluorochemical treatment on altering the wettability from liquid-wetting to intermediate gas-wetting. The wettability of the Berea sandstone was analyzed before and after chemical treatment over a temperature range of 25−83 °C. The outcrop core samples of Berea sandstone used in this investigation exhibited an average porosity and permeability of 20% and 100 mD, respectively. The experimental results indicate that the application of chemical treatment has the potential to alter the wettability of Berea sandstone, transitioning it from a state of liquidwetting to gas-wetting at standard temperatures. The chemical treatment alters the wettability from liquid-wet to intermediate gaswet at higher temperatures. Furthermore, the alteration of wettability substantially improves the mobility of the oil phase and decreases the residual saturation of the oil, thereby aiding the reduction of liquid accumulation around the wellbore. According to this research, altering the wettability of the rock surrounding the wellbore in gas condensate reservoirs from a state of strong liquidwet to gas-wet has the potential to enhance the deliverability of gas wells and improve injectivity in the field.

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“…Therefore, the surface of the carbonate becomes more negatively charged, which leads to the spontaneous desorption of negatively charged oil constituents. The presence of surfactants, such as erucamidopropylbetaine [35,36] or ethoxylated quaternary ammonium Gemini surfactant [37,38], enhanced wettability alteration by CAs.…”

Section: Introductionmentioning

confidence: 99%

Study of Wettability Alteration of Hydrophobic Carbonate Rock by Surfactant-Containing Chelating Agent Solutions

Yunusov,

Davletshina,

Klimov

et al. 2023

Applied Sciences

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Chelating agents’ application for well stimulation is gaining more and more interest, as they can perform under harsh conditions. However, the mutual influence of surfactants and chelating agents on the wettability alteration of hydrophobic carbonate rock under conditions of high-temperature well stimulation is relatively unexplored. This paper aims to study interfacial processes on the surface of hydrophobic rock in the presence of the EDTA-based chelating agent and surfactants of different classes. Cationic (cetyltrimethylammonium bromide, CTAB, and cetylpyridinium bromide, CPB), anionic (sodium dodecyl sulfate, SDS), and amhoteric (alkyldimethyl aminooxide, AO) surfactants were studied. Wettability alteration of model hydrophobic rock was studied under conditions specific to well stimulation. It was shown that chelating agent (CA) alone and its mixture with SDS could not lead to sufficient wettability alteration. CTAB, CPB, and AO were able to change the wettability effectively. A synergistic effect between CA and these surfactants was observed and a possible mechanism was proposed. AO was selected as the most promising surfactant. The influence of surfactant on the CA’s dissolution capacity towards carbonate rock was investigated; dissolution capacity strongly depends on wettability alteration. Finally, the effect of CA, AO, and their mixture on the wettability of aged reservoir rock was studied and the absence of negative effects was proven.

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Wettability Alteration of Carbonate Rock by Chelating Agents and Viscoelastic Surfactants: Synergetic Impact

Cited by 11 publications

References 41 publications

Synthesis and Evaluation of Mesoporous Silica Nanoparticle and its Application in Chemical Enhanced oil Recovery

Synthesis and Evaluation of Mesoporous Silica Nanoparticle and its Application in Chemical Enhanced oil Recovery

Wettability Alteration of Berea Sandstone for Gas Condensate Applications

Study of Wettability Alteration of Hydrophobic Carbonate Rock by Surfactant-Containing Chelating Agent Solutions

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