Adsorption Study of Novel Gemini Cationic Surfactant in Carbonate Reservoir Cores—Influence of Critical Parameters

Khan, Sarmad Zafar; Gbadamosi, Afeez; Norrman, Kion; Zhou, Xianmin; Hussain, Syed Muhammad Shakil; Patil, Shirish; Kamal, Muhammad Shahzad

doi:10.3390/ma15072527

Cited by 17 publications

(12 citation statements)

References 41 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…The surfactant concentration in the flood effluent was determined using the effective potentiometric HPLC (high-performance liquid chromatography) technique. ,− An Agilent 1200 series HPLC system featuring an attached evaporative light scattering detector (ELSD) was utilized. Acetonitrile (C 2 H 3 N) served as mobile phase A, while a 0.1 M ammonium formate (NH 4 COOH) with a pH of 4.3 adjusted by formic acid (CH 2 O 2 ) acted as the carrier phase B.…”

Section: Experimental Workmentioning

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

Self Cite

View full text Add to dashboard Cite

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.

show abstract

Section: Experimental Workmentioning

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

Self Cite

View full text Add to dashboard Cite

show abstract

“…Surfactant retention by the core sample was also evaluated by analyzing the coreflood effluent. Several evaluation methods are available in the literature, including potentiometric high-performance liquid chromatography (HPLC), ,,− Hyamine titration, and UV–visible spectroscopy, among others. In this work, an Agilent 1200 series HPLC was used with acetonitrile (C 2 H 3 N) as the mobile phase A.…”

Section: Experimental Workmentioning

confidence: 99%

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

et al. 2023

Self Cite

View full text Add to dashboard Cite

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.

show abstract

“…Dynamic adsorption of a cationic Gemini surfactant on Indiana limestone was studied recently. 29 Outcomes showed that decreasing the surfactant concentration and increasing the flow rates will result in decreasing surfactant retention. Most recent research shows the adsorption mechanisms of a cationic Gemini surfactant onto sandstone and carbonate rocks.…”

Section: Introductionmentioning

confidence: 99%

“…Results showed that shorter spacer length showed a smaller adsorption plateau because of the same reason. Dynamic adsorption of a cationic Gemini surfactant on Indiana limestone was studied recently . Outcomes showed that decreasing the surfactant concentration and increasing the flow rates will result in decreasing surfactant retention.…”

Section: Introductionmentioning

confidence: 99%

Adsorption Characteristics of a Cationic Gemini Surfactant on Carbonate Outcrops: Adsorption Reduction Using Methylene Blue

et al. 2023

Self Cite

View full text Add to dashboard Cite

Surfactant adsorption has been a great challenge for surfactant-based chemically enhanced oil recovery (cEOR) techniques as it directly reflects the overall efficiency of a cEOR project. The static adsorption of an in-house-synthesized cationic Gemini surfactant (GS12) has been investigated on carbonate outcrops as a function of concentration, time, salinity, and temperature. Three different types of carbonate outcrop samples taken from the Al-Lidam area with an increasing percentage of silica and clay impurities were investigated. It was found that the higher the presence of silicate and clay minerals in the carbonate outcrops, the higher will be the surfactant adsorption. The adsorption of GS12 was found to decrease at elevated temperatures and in a highly saline environment, especially at very high concentrations of divalent salts (CaCl 2 and MgCl 2 ). In addition, a novel adsorption inhibitor�methylene blue�has been proposed in this study, which reduced the surfactant adsorption dramatically on carbonate outcrops. The GS12 adsorption on carbonate samples 1, 2, and 3 was reduced to 0.14 mg/g-rock, 0.48 mg/g-rock, and 2.31 mg/g-rock, respectively, by the addition of 500 ppm methylene blue in a 1500 ppm surfactant solution. Moreover, curve fitting was also performed to analyze the adsorption isotherm and kinetic data. Redlich−Peterson and pseudo-second-order models were found to be the best to describe the adsorption isotherm and kinetics, respectively.

show abstract

Adsorption Study of Novel Gemini Cationic Surfactant in Carbonate Reservoir Cores—Influence of Critical Parameters

Cited by 17 publications

References 41 publications

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

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

Adsorption Characteristics of a Cationic Gemini Surfactant on Carbonate Outcrops: Adsorption Reduction Using Methylene Blue

Contact Info

Product

Resources

About