Synthesis and properties of zwitterionic gemini surfactants for enhancing oil recovery

Liu, Jinhua; Liu, Zhe; Yuan, Tingjiao; Wang, Chaowei; Gao, Ruimin; Hu, Guangfa; Xu, Jingshen; Zhao, Jianshe

doi:10.1016/j.molliq.2020.113179

Cited by 28 publications

(13 citation statements)

References 20 publications

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“…The common spacers of Gemini surfactants include azobenzene, ethylene oxide, perylene tetracarboxylic diamide, stilbene, polyoxyethylene, tetracarboxylic diamide, 2-butynyl, methylene, and polyether. − Finally, Gemini surfactants are named based on the length of the spacer group and the hydrophobic tail. For example, a surfactant is named t-s-t where t denotes the number of carbon atoms in the hydrophobic tail and s represents the number of carbon atoms in the spacer group. , Several studies have been conducted recently to evaluate oil recovery by Gemini surfactants as EOR agents. − …”

Section: Fundamentals Of Surfactant Floodingmentioning

confidence: 99%

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Oil Recovery Performance by Surfactant Flooding: A Perspective on Multiscale Evaluation Methods

et al. 2022

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Chemical-enhanced oil recovery (cEOR) is a class of techniques commonly used to extract hydrocarbon fluids from reservoir rocks beyond conventional waterflooding. Surfactants are among the chemical agents employed in a cEOR process, as they aid in enhancing oil recovery by lowering the oil–water interfacial tension (IFT) and altering the rock wettability toward less oil-wet conditions. Understanding the flow characteristics and mechanisms involved during surfactant flooding helps improve the performance of injected surfactants and results in higher oil recovery. The objective of this review is to outline the recent applications of the different methods employed to understand the behavior and mechanisms involved during surfactant-enhanced oil recovery. The review begins with a general background highlighting the basic characteristics of surfactants and the main mechanisms by which they exert their influence. Recent studies conducted to investigate the oil recovery performance through different methods are then presented, including traditional coreflooding experiments, microfluidics studies, and oil recovery through sand packs. The methodology of the analysis and the interpretation of the data obtained from the different oil recovery tests, including oil recovery factor, pressure data, and relative permeability, are also described. Pore-scale analysis and imaging methods including nuclear magnetic resonance (NMR), magnetic resonance imaging (MRI), and X-ray medical and microcomputed tomography (μCT) scanning and their applicability in assessing the recovery performance are described. Finally, a few examples of field monitoring methods for surfactant flooding are highlighted. This review provides knowledge of the different multiscale evaluation methods and their applicability during surfactant flooding.

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Section: Fundamentals Of Surfactant Floodingmentioning

confidence: 99%

“…Liu et al synthesized and evaluated several double and quaternary ammonium salts and zwitterionic surfactants. Among those surfactants, YLZ-3 was shown to be the most effective wettability modifier.…”

Section: Surfactant-based Oil Recovery Studiesmentioning

confidence: 99%

Oil Recovery Performance by Surfactant Flooding: A Perspective on Multiscale Evaluation Methods

et al. 2022

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“…Their favorable wettability, foaming, and rheological characteristics, combined with high solubility in water, make them highly attractive for various applications in the oil and gas industry. − Distinguishing themselves from conventional surfactants, Gemini surfactants incorporate a spacer positioned at or near the hydrophilic heads. This spacer connects multiple hydrophobic tail groups and hydrophilic head groups. , Despite their exceptional attributes, there is a scarcity of studies that focus on discussing the practical utilization of Gemini surfactants, particularly within the context of cEOR in carbonate rocks. − Pal et al investigated cationic Gemini surfactants through sandpack flooding with surfactant–polymer formulations. The tests achieved additional oil recoveries of 29.8–34.6%.…”

Section: Introductionmentioning

confidence: 99%

Role of Injection Rate on Chemically Enhanced Oil Recovery Using a Gemini Surfactant under Harsh Conditions

Al-Azani,

Abu-Khamsin,

Kamal

et al. 2024

Energy Fuels

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Introducing surfactants into a hydrocarbon reservoir is considered one of the most effective methods for enhanced oil recovery (EOR), mainly due to their ability to reduce interfacial tension and modify rock wettability. However, experimental parameters play a significant role in surfactant flooding. As an important design parameter, this work specifically investigates how the injection rate influences the oil recovery performance of a locally synthesized Gemini surfactant. Four core flooding experiments on carbonate core samples were conducted, each at a specific injection rate (0.10, 0.25, 0.50, and 1.00 cc/min) under simulated reservoir conditions. The conditions include a temperature of 100 °C, pressures exceeding 3000 psi, and formation water and seawater salinities of 213,768 and 57,745 ppm, respectively. Each experiment involved initial continuous seawater flooding followed by continuous flooding with a 2500 ppm surfactant solution. The results revealed an increasing trend in the recovery factor with injection rates caused by seawater flooding. Recovery factors at 0.10, 0.25, and 0.50 cc/min rates were 43.7, 46.6, and 49.1% of the oil initially in place (OOIP), respectively. However, at 1.00 cc/min, the factor decreased to 48.1% OOIP after seawater flooding, possibly due to poor conformance control. In contrast, the recovery factor at the end of surfactant flooding was higher at lower injection rates (i.e., 0.10 and 0.25 cc/min), reflecting sufficient time for the surfactant to alter rock wettability and mobilize oil with 0.25 cc/min as the optimum tested rate. However, effluent analysis revealed that slower injection rates correlated with higher dynamic retention (e.g., 0.383 mg/g of rock at 0.10 cc/min) compared to higher injection rates (e.g., 0.295 mg/g of rock at 1.00 cc/ min). This implies a trade-off in choosing the injection rate when using the Gemini surfactant: balancing high oil recovery against minimizing dynamic retention. Consequently, this study emphasizes the need to carefully consider injection rates in surfactant flooding for optimal EOR outcomes.

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“…In the literature, numerous studies have been carried out to investigate the applicability and effectiveness of various surfactant/chemical formulations in carbonate reservoirs. ,,− However, limited studies focus on using single component surfactants for oil recovery applications. Additionally, a few studies are available on the applications of cationic Gemini and zwitterionic surfactants for oil recovery. − These two classes of surfactants are of great interest to the oil industry due to their superior characteristics including their high thermal stability, high solubility in saline brines, low critical micelle concentrations (CMCs), rheological properties, and ability to lower the oil/water IFT. − Several attempts have been made to synthesize and evaluate different cationic Gemini and zwitterionic surfactants to withstand the HTHS conditions of hydrocarbon reservoirs. − …”

Section: Introductionmentioning

confidence: 99%

Enhanced Oil Recovery in Carbonate Reservoirs Using Single Component Synthesized Surfactants under Harsh Reservoir Conditions

et al. 2023

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Surfactants are commonly used for enhanced oil recovery (EOR) applications in carbonate hydrocarbon reservoirs due to their ability to reduce oil/water interfacial tension (IFT) and/or alter rock wettability toward more water-wet conditions. They are usually used as formulations consisting of more than two surfactants to achieve optimum performance. Although this approach may result in extra recovery in coreflooding experiments, there is a risk of chromatographic separation and potential phase separation when these surfactants are injected into the reservoir. The current study, however, focuses on injecting a single component ethoxylated quaternary ammonium cationic Gemini surfactant (GS) or a betaine-type zwitterionic surfactant (ZIS), both synthesized in-house, to mitigate these potential issues. Several coreflooding experiments were conducted using Indiana limestone samples at 100 °C, pressures greater than 3000 psi, and seawater and formation water salinities of 57,745 ppm and 213,768, respectively. Continuous injection of either surfactant solution (at 2500 ppm in seawater) after seawater flooding recovered almost 11−12% of the initial oil in the core (OOIP). The results demonstrate that the GS or the ZIS alone can achieve this relatively high oil recovery without the need for additional cosolvent(s) or cosurfactant(s), unlike most of the previously developed surfactant formulations. Injecting a one-pore-volume slug of a standard acrylamide copolymer at 2000 ppm between the seawater and the surfactant floods increased the oil recovery by either surfactant to around 16−17% OOIP. This improvement in oil recovery was mainly due to wettability alteration from oil-wet to intermediate-wet conditions, as revealed by the contact angle and oil/water IFT measurements. Effluent analysis of the produced aqueous phase showed surfactant dynamic retention values of 0.44 and 0.61 mg/g-rock of both the GS and the ZIS, respectively. Such high oil recovery and low dynamic retention reflect the high efficiency of the GS and the ZIS for EOR applications in carbonate reservoirs.

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Synthesis and properties of zwitterionic gemini surfactants for enhancing oil recovery

Cited by 28 publications

References 20 publications

Oil Recovery Performance by Surfactant Flooding: A Perspective on Multiscale Evaluation Methods

Oil Recovery Performance by Surfactant Flooding: A Perspective on Multiscale Evaluation Methods

Role of Injection Rate on Chemically Enhanced Oil Recovery Using a Gemini Surfactant under Harsh Conditions

Enhanced Oil Recovery in Carbonate Reservoirs Using Single Component Synthesized Surfactants under Harsh Reservoir Conditions

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