Enhanced Oil Recovery from the Methyl Ester Sulfonate Derived from Flaxseed Oil: Interfacial, Adsorption and Rock Wetting Characteristics

Kesarwani, Himanshu; Mandal, Ajay; Sharma, Shivanjali

doi:10.1002/slct.202104593

Cited by 13 publications

(6 citation statements)

References 77 publications

(182 reference statements)

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“…49 The stretching at 3656.96 cm −1 can be attributed to the presence of a hydroxyl group. 50,51 The stretching band at ∼434.27 is present in the spectrum because of the chemical bond between Zn and O atoms in ZnO nanoparticles. 52 These observations in the FTIR analysis confirm the formation of the TPN.…”

Section: Resultsmentioning

confidence: 99%

Cement Slurry Design for High-Pressure, High-Temperature Wellbores Using Polymer Nanocomposite: A Laboratory Scale Study Based on the Compressive Strength and Fluid Loss

et al. 2022

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For the successful cementing operation of petroleum wells, the design of cement slurry plays a crucial role. Cement slurry must address the requirements of higher compressive strength; lower fluid loss; durability; and high-pressure, high-temperature (HPHT) challenges. A large number of chemical additives in cement slurry affects the required rheological properties; therefore, the development of multifunctional additives is desirable. In the present study, this problem has been addressed with the use of a single polymeric nanocomposite additive to address multiple requirements. A novel tetrapolymer nanocomposite (TPN) was synthesized in the laboratory by in situ polymerization in the presence of zinc oxide nanoparticles. Four monomers, namely acrylamide, 2-acrylamido-2-methylpropanesulfonic acid, vinyl phosphonic acid, and N-[3-(dimethylamino)propyl] methacrylamide, were selected for the in situ polymerization reaction. The synthesized product was characterized using 1H NMR, FTIR, and TGA techniques. Laboratory-synthesized TPN was mixed in varying concentrations in the cement slurry as an additive. The performance of the enhanced cement slurry was then evaluated by performing compressive strength analysis and a filtration test using an ultrasonic cement analyzer and an HPHT filter press, respectively. These experimental analyses show that the addition of the TPN improved the compressive strength of the cement slurry and, at the same time, abbreviated the fluid loss, which is desired for efficient cementing operation. With the addition of 1.0% by weight of cement (BWOC) of TPN, the compressive strength increased by ∼136% compared with base cement. Additionally, this small dosage also reduced HPHT fluid loss by ∼67%. This experimental investigation shows that the novel TPN additive is capable of improving the efficacy of oil-well cement slurry at high-temperature conditions without compromising on thickening time because the additive also improved the waiting-on-cement time for HPHT conditions.

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Section: Resultsmentioning

confidence: 99%

Cement Slurry Design for High-Pressure, High-Temperature Wellbores Using Polymer Nanocomposite: A Laboratory Scale Study Based on the Compressive Strength and Fluid Loss

et al. 2022

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“…During injection, surfactants are adsorbed on the rock surface due to physical and chemical interactions and are removed from the fluid–fluid system. Surfactant adsorption reduces its concentration in the solution and weakens it in reducing the interfacial tension. , Adsorption of the AOCS onto a carbonated porous medium was evaluated by a flooding test. In this method, adsorption is directly calculated based on the reduction of surfactant concentration in terms of the volume of injected fluid.…”

Section: Methodsmentioning

confidence: 99%

Chemical Enhanced Oil Recovery from Carbonate Reservoirs by Coherent Surfactant and Surfactant–Alkali (SA) Slug Injection Using a Green Cationic Surfactant Synthesized from Avocado Oil

Nowrouzi,

Mohammadi,

Khaksar Manshad

2023

Energy Fuels

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Natural surfactants are proposed as alternatives to chemical surfactants in enhanced oil recovery (EOR) process. This research involved the synthesis and analysis of a new green cationic surfactant extracted from avocado oil. We studied the properties of the surfactant solutions by conducting tests on the surface tension, emulsion formation, and compatibility with varying levels of salinity. After that, in order to study the efficiency of the surfactant, rudimentary tests of EOR, including surface and interfacial tension (IFT), contact angle, adsorption in porous medium, and two injection schemes of coherent surfactant and surfactant–alkali (SA) slug, were performed. The main functional groups in the avocado oil cationic surfactant (AOCS) include amide, amine, and sulfate groups, which were confirmed by related analyses. The estimated critical micelle concentration (CMC) of the avocado oil-based cationic surfactant (AOCS) was found to be approximately 725 ± 25 ppm (ppm). At this concentration, the interfacial tension between the surfactant and the oil surrounding medium was measured to be 0.316 millinewtons per meter (mN/m). Furthermore, the interfacial tension decreased to 0.063 and 0.035 mN/m under optimal salinity and alkalinity, respectively. The value of interfacial tension after about 35 days of the solution’s shelf life was out of the desired range. The contact angle decreased from 126.81 to 61.53° after 180 min, and the wettability of carbonate altered from oleophilic to hydrophilic by the surfactant. The AOCS was compatible with up to 60,000 ppm salinity, and after the injection of 2.5 PV, 6.2 wt % of it was adsorbed on the carbonate. The coherent injection of the AOCS increased the oil recovery by 25.6% to a total recovery of 80.1%. In another method, injecting a slug of SA with a volume equal to 0.5 pore volumes (PV) resulted in a significant increase in oil recovery, amounting to a 23.4% improvement, and the total recovery reached 77.7%.

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“…Different types of force, such as van der Waals force, structural force, and electrostatic force are the main reasons for this adhesion to exist and, as a result, homogeneous fluid distribution will occur in porous media . As the two phases coexist in the porous media, one of them, which has the greater adhesive force, will adsorb on the surface and the surface rock will be known as the stronger wetting phase . Sandstone rocks act as an intermediate, to water-wet; on the other hand, carbonate rocks are intermediate to oil wet .…”

Section: Role Of Natural Surfactant In Eormentioning

confidence: 99%

“…120 As the two phases coexist in the porous media, one of them, which has the greater adhesive force, will adsorb on the surface and the surface rock will be known as the stronger wetting phase. 170 Sandstone rocks act as an intermediate, to water-wet; on the other hand, carbonate rocks are intermediate to oil wet. 171 Rock's wettability can be indicated by the angle between the rock surface and the oil drop in such a matter that, if the mentioned angle is >90°, the rock surface known as oil wet; if the angle is 90°, it is neutral; and if it is <90°, it is considered to be water-wet (see Figure 9).…”

Section: Wettability Alterationmentioning

confidence: 99%

Review of the Application of Natural Surfactants in Enhanced Oil Recovery: State-of-the-Art and Perspectives

2023

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Injecting surfactant by means of chemical enhanced oil recovery (cEOR) has acquired predominant attention in improving oil recovery by changing either fluid/rock and/or fluid/fluid interaction due to ion-pair forming and/or surfactant adsorption on the rock surface. As the main surfactant role in EOR, IFT reduction refers to adsorbing of surfactant molecules on the residual oil/water interface, which causes an increase in capillary number; as a result, trapped oil drops in porous media get free and start to move through the pore space toward the production well. The toxic nature, excessive cost, and environmental issues are the obvious limitations in applying the chemical surfactants in EOR, hence, looking for a less-expensive and eco-friendly type of surfactant has become a significant task to researchers to study the natural surfactant as an alternative to chemical surfactants. A deep understanding about the classification of natural surfactants, fabrication methods, and the difference between each class is crucial to propose a new plant-derived natural surfactant. This study tried to review up-to-date published studies related to the natural surfactant types and prepare a comprehensive catalog respective to natural surfactant that helps researchers with regard to future work in natural surfactant application in EOR. In addition, comparisons of each class performance and the impact of nanoparticles and the salinity on them in reducing IFT, altering wettability, and improving the recovery factor have been investigated. It had been concluded that natural surfactant can be produced from different plant parts (leaf, root, steam, fruit, and seed) based on the fabrication method. Natural surfactants synthesized from seed oil are stronger, compared with those extracted from the plant part (i.e., IFT reduction by 98%). Generally, injecting natural surfactants expressed low to high performance in improving the ultimate oil recovery from 2% to 40% original oil in place (OOIP).

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Enhanced Oil Recovery from the Methyl Ester Sulfonate Derived from Flaxseed Oil: Interfacial, Adsorption and Rock Wetting Characteristics

Cited by 13 publications

References 77 publications

Cement Slurry Design for High-Pressure, High-Temperature Wellbores Using Polymer Nanocomposite: A Laboratory Scale Study Based on the Compressive Strength and Fluid Loss

Cement Slurry Design for High-Pressure, High-Temperature Wellbores Using Polymer Nanocomposite: A Laboratory Scale Study Based on the Compressive Strength and Fluid Loss

Chemical Enhanced Oil Recovery from Carbonate Reservoirs by Coherent Surfactant and Surfactant–Alkali (SA) Slug Injection Using a Green Cationic Surfactant Synthesized from Avocado Oil

Review of the Application of Natural Surfactants in Enhanced Oil Recovery: State-of-the-Art and Perspectives

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