Static adsorption of anionic surfactant onto crushed Berea sandstone

Azam, Muhammad Rizwan; Tan, Isa M.; Ismail, Lukman; Mushtaq, Muhammad; Nadeem, Muhammad; Sagir, Muhammad

doi:10.1007/s13202-013-0057-y

Cited by 125 publications

(80 citation statements)

References 18 publications

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“…The sharp increase in the surfactant adsorption in region II is due to the formation of surface aggregates, also called hemi‐micelles. The formation of surface aggregates takes place due to lateral interactions between the surfactant hydrophobic chain and surface monomer . In region III, electrostatic interactions are diminished and only lateral interactions are present.…”

Section: Resultsmentioning

confidence: 99%

Novel fluorinated surfactants for enhanced oil recovery in carbonate reservoirs

et al. 2016

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Novel surfactant-polymer (SP) formulations containing fluorinated amphoteric surfactant (surfactant-A) and fluorinated anionic surfactant (surfactant-B) with partially hydrolyzed polyacrylamide (HPAM) were evaluated for enhanced oil recovery applications in carbonate reservoirs. Thermal stability, rheological properties, interfacial tension, and adsorption on the mineral surface were measured. The effects of the surfactant type, surfactant concentration, temperature, and salinity on the rheological properties of the SP systems were examined. Both surfactants were found to be thermally stable at a high temperature (90 8C). Surfactant-B decreased the viscosity and the storage modulus of the HPAM. Surfactant-A had no influence on the rheological properties of the HPAM. Surfactant-A showed complete solubility and thermal stability in seawater at 90 8C. Only surfactant-A was used in adsorption, interfacial tension, and core flooding experiments, since surfactant-B was not completely soluble in seawater and therefore was limited to deionized water. A decrease in oil/water interfacial tension (IFT) of almost one order of magnitude was observed when adding surfactant-A. However, betaine-based co-surfactant reduced the IFT to 10 À3 mN/m. An adsorption isotherm showed that the maximum adsorption of surfactant-A was 1 mg per g of rock. Core flooding experiments showed 42 % additional oil recovery using 2.5 g/L (2500 ppm) HPAM and 0.001 g/g (0.1 mass%) amphoteric surfactant at 90 8C.

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Section: Resultsmentioning

confidence: 99%

Novel fluorinated surfactants for enhanced oil recovery in carbonate reservoirs

et al. 2016

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“…The mixtures were then subjected to continuous mixing on a VWR incubating orbital shaker for 24 h at the temperature of interest (25, 50 and 65ºC) for all experiments. Thereafter, the mixtures were cooled and centrifuged at 13,000 rpm for at least 15 min and the supernatants were extracted for analysis (Azam, 2013). The Jenway 6850UV-Vis spectrophotometer was used to measure the absorbance of samples over a wavelength range of 250-650 nm.…”

Section: Adsorption Testmentioning

confidence: 99%

“…The phenomena by which surfactant adsorbs to solid surface from aqueous solution involves different mechanisms such as: ion exchange, ion pairing, hydrogen bonding, Van der Waal force and hydrophobic interaction (Norde, 1996;Nakanishi et al, 2001;Rosen, 2004). Surfactant adsorption however, is a complex process that is greatly influenced by environmental factors such as solid composition, aqueous solution composition, ionic strength, pH as well as the nature and concentration of surfactants (Azam et al, 2013).…”

Section: Introductionmentioning

confidence: 99%

Comparative Study on Adsorption of Biologically Generated Surface Active Agents on Carbonate and Sandstone Rock Surfaces

Udoh¹

2019

Int.J.Curr.Res.Aca.Rev.

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Article Info Surfactant adsorption at rock-fluid interface is fundamental to wettability alteration that is relevant to enhanced oil recovery process but the extent of this adsorption can also impact the economic viability of the surfactant application in the process. In this paper, adsorptions of two biologically generated surfactants (rhamnolipid and greenzyme) on carbonate and sandstone rock surfaces have been studied and reported. The rocks' main components and physicochemical makeup were determined with the use of X-ray diffraction and scanning electron microscopy. The compositional analyses of sandstone and carbonate rocks show the dominant components as quartz and calcite respectively. From the adsorption investigations, rhamnolipid tends to show higher surface activity than greenzyme. It also shows stronger affinity for sandstone rock surface than carbonate while greenzyme shows stronger affinity for carbonate surface. Furthermore, decrease in adsorptions of rhamnolipid and greenzyme with increase in temperature and decrease in salinity was observed in all the systems. Finally, the adsorption models suggest rhamnolipid adsorption process to be mono-layer in nature, while greenzyme adsorption tends to be monolayer at low adsorption and heterogeneous at high adsorption.

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“…Several studies determined that most surfactants cannot be used in harsh reservoir conditions. Therefore, their poor performance at high-temperature and salinity conditions has led to developing new technologies, chemicals, and formulations in order to overcome these harsh conditions (Azam et al 2013;Karnanda et al 2013;Sheng 2015).…”

Section: Introductionmentioning

confidence: 99%

The effect of surfactant concentration, salinity, temperature, and pH on surfactant adsorption for chemical enhanced oil recovery: a review

Belhaj

Elraies

Mahmood

et al. 2019

J Petrol Explor Prod Technol

300

131

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Enhanced oil recovery (EOR) processes have a great potential to maximize oil recovery factor of the existing reservoirs, where a significant volume of the unrecovered oil after conventional methods is targeted. Application of chemical EOR techniques includes the process of injecting different types of chemicals into a reservoir to improve the overall sweep efficiency. Surfactant flooding is one of the chemical EOR used to reduce the oil-water interfacial tension and to mobilize residual oil toward producing wells. Throughout the process of surfactant flooding, selecting a suitable surfactant for the reservoir conditions is quite challenging. Surfactants tend to be the major factor associated with the cost of an EOR process, and losing surfactants leads to substantial economic losses. This process could encounter a significant loss of surfactant due to adsorption into the porous media. Surfactant concentration, salinity, temperature, and pH were found to be as the main factors that influence the surfactant adsorption on reservoir rocks. Most of the research has been conducted in low-temperature and low-salinity conditions. Only limited studies were conducted in high-temperature and high-salinity (HT/HS) conditions due to the challenging for implementation of surfactant flooding in these conditions. This paper, therefore, focuses on the reviews of the studies conducted on surfactant adsorption for different surfactant types on different reservoir rocks under different reservoir conditions, and the influence of surfactant concentration, salinity, temperature, and pH on surfactant adsorption.

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Static adsorption of anionic surfactant onto crushed Berea sandstone

Cited by 125 publications

References 18 publications

Novel fluorinated surfactants for enhanced oil recovery in carbonate reservoirs

Novel fluorinated surfactants for enhanced oil recovery in carbonate reservoirs

Comparative Study on Adsorption of Biologically Generated Surface Active Agents on Carbonate and Sandstone Rock Surfaces

The effect of surfactant concentration, salinity, temperature, and pH on surfactant adsorption for chemical enhanced oil recovery: a review

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