Static adsorption of a new cationic biosurfactant on carbonate minerals: Application to EOR

Bassir, Seyed Mojtaba; Shadizadeh, Seyed Reza

doi:10.1080/10916466.2020.1727922

Cited by 10 publications

(2 citation statements)

References 18 publications

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“…To resolve the unfavorable reservoir rock wettability, many enhanced oil recovery (EOR) techniques have been proposed for the wettability alteration such as using surfactants (Alagic and Skauge, 2010;Bassir and Shadizadeh, 2020;Das et al 2021;Hou et al 2021;Johannessen and Spildo, 2014;Khayati et al 2020;Sekerbayeva et al 2020;Shi et al 2021), nanoparticles (Abhishek et al 2018a(Abhishek et al , 2018bHamouda and Abhishek, 2019;Olayiwola and Dejam, 2020;Shirazi et al 2019), ionic liquids (Bera et al 2020;Nandwani et al 2019;Pillai and Mandal, 2019;Velusamy et al 2017) and modified salinity brine injection (Hao et al 2019).…”

Section: Introductionmentioning

confidence: 99%

Towards prediction of oil recovery by spontaneous imbibition of modified salinity brine into limestone rocks: A scaling study

Bassir

Behbahani

Shahbazi

et al. 2022

J Petrol Explor Prod Technol

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Spontaneous imbibition is a key mechanism of oil recovery in naturally fractured reservoirs. Many enhanced oil recovery techniques, such as modified salinity brine injection, have been suggested to improve spontaneous imbibition efficiency. To predict oil recovery by spontaneous imbibition process, scaling equations have been developed in the literature where almost none of them include the effect of two critical aspects. One aspect is the different ionic composition of injecting brine from connate brine. Another aspect is the effect of combination/interaction of a lower salinity imbibing (injecting) brine with connate brine. This research takes into account these two aspects to propose a new empirical scaling equation to scale oil recovery by modified salinity imbibing brines in limestone rocks. For this purpose, the results of available 59 tests from 14 references performed on various limestone rock samples collected from different formations and regions were used. The tests had been performed at high temperatures and on aged cores, which makes the proposed scaling equation more realistic and applicable to reservoir conditions. For the first time, the imbibing and connate brines ionic strengths are included in the equation due to the mechanism of the modified salinity brine injection method. In addition, the scaled spontaneous imbibition recovery data by the new equation was matched using two mathematical expressions based on the Aronofsky model and Fries and Dreyer model which can be used to derive transfer functions for simulation of spontaneous imbibition oil recovery by modified salinity brine injection in fractured limestone reservoirs.

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Section: Introductionmentioning

confidence: 99%

Towards prediction of oil recovery by spontaneous imbibition of modified salinity brine into limestone rocks: A scaling study

Bassir

Behbahani

Shahbazi

et al. 2022

J Petrol Explor Prod Technol

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“…They also synergized the advantages of xanthan gum and silica nanoparticles and gained better results for IFT reduction and wettability alteration . To date, various experimental works have been conducted on the mechanisms of wettability change of oil-wet rock by natural potent surfactants extracted from various plants. − …”

Section: Introductionmentioning

confidence: 99%

Characterization, Micellization Behavior, and Performance of a Novel Surfactant Derived from Gundelia tournefortii Plant during Chemical Enhanced Oil Recovery

2021

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Surface active agents or surfactants optimize the chemical enhanced oil recovery (EOR) operations. Since their first use, chemical surfactant applications have posed challenges because of their environmental concerns and high material expenses. The current study introduces the Gundelia tournefortii (GT) plant as a cheap and environmentally friendly source of nonionic amphiphiles for chemical EOR applications. The GT surfactant extract was evaluated using both analytical characterization tests and EOR-related experiments. Fourier transform infrared spectroscopy and thermogravimetric analysis showed the presence of amphiphile molecules in the plant extract and thermal weight loss of the novel introduced saponin-rich extract, respectively. Critical micelle concentration was characterized using various complementary tests of pH, electrical conductivity, density, turbidity, interfacial tension measurements, and micelle formation effects on properties of the solution. Foaming characterization and wettability alteration also confirmed the micellization effects. Foaming and foam half-life time parameters were also evaluated. Interfacial tension and wettability optimization by the GT surfactant solution were measured to validate its potential to enhance oil recovery, achieving a decrease in the interfacial tension from 28 to 3 mN/m and a change in the contact angle from oil-wetting to water-wetting (160 to 20°). Core flooding experiments were conducted to observe and validate the efficiency of the wettability alteration and interfacial tension reduction, achieving a 19.8% increase in oil recovery compared to seawater flooding and a final oil recovery of 66.33%. Relative permeability curves of displacing and displaced fluids were computed and analyzed as wettability alteration validation and for the residual oil calculation.

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Spontaneous imbibition of modified salinity brine into different lithologies: an improvement of comprehensive scaling used for fractured reservoir simulation

Bassir,

Shokrollahzadeh Behbahani,

Shahbazi

et al. 2024

J Petrol Explor Prod Technol

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Spontaneous water imbibition into matrix blocks can be a significant oil recovery mechanism in fractured reservoirs. Many enhanced oil recovery methods, such as injection of modified salinity brine, are proposed for improving spontaneous imbibition efficacy. Many scaling equations are developed in the literature to predict spontaneous imbibition oil recovery. However, almost none of them included the impact of the diversity in ionic composition of injected and connate brines and the blending/interaction of a low salinity imbibing brine with a higher salinity connate brine. In this research, these two issues are included to propose new scaling equations for the scaling of spontaneous imbibition oil recovery by modified salinity imbibing brines. This study uses experimental data of the spontaneous imbibition of modified salinity brines into oil-saturated rock samples with different lithologies containing an irreducible high salinity connate brine. The collected tests from the literature were performed at high temperatures and on aged altered wettability cores. The results of 110 available spontaneous imbibition laboratory experiments (85, 12 and 13 tests on chalks, dolomites and sandstones, respectively) are gathered. This research initially shows the poor ability of three selected convenient scaling equations from the literature to scale imbibition recovery by modified salinity brine. Then, our newly proposed technique to find the scaling equation for spontaneous imbibition recovery by modified salinity brine, during the abovementioned conditions in limestones (Bassir et al. in J Pet Explor Prod Technol 13(1): 79–99, 2023. https://doi.org/10.1007/s13202-022-01537-7) is used in chalks, dolomites and sandstones to develop the three new scaling equations. Finally, a new general equation to scale imbibition recovery by modified salinity brine for all four lithologies is presented. Moreover, for each of the four datasets (chalk, dolomite, sandstone and all the four lithologies), the scaled data by the new equations is matched by two mathematical expressions based on the Aronofsky et al. model and the Fries and Dreyer model. These mathematical expressions can be used to develop transfer functions in reservoir simulators for a more accurate prediction of oil recovery by spontaneous imbibition of modified salinity brine in fractured reservoirs.

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Static adsorption of a new cationic biosurfactant on carbonate minerals: Application to EOR

Cited by 10 publications

References 18 publications

Towards prediction of oil recovery by spontaneous imbibition of modified salinity brine into limestone rocks: A scaling study

Towards prediction of oil recovery by spontaneous imbibition of modified salinity brine into limestone rocks: A scaling study

Characterization, Micellization Behavior, and Performance of a Novel Surfactant Derived from Gundelia tournefortii Plant during Chemical Enhanced Oil Recovery

Spontaneous imbibition of modified salinity brine into different lithologies: an improvement of comprehensive scaling used for fractured reservoir simulation

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