Effect of temperature, pressure, salinity, and surfactant concentration on IFT for surfactant flooding optimization

Karnanda, Wimpy; Benzagouta, M. S.; AlQuraishi, Abdulrahman A.; Amro, Mohammed

doi:10.1007/s12517-012-0605-7

Cited by 107 publications

(64 citation statements)

References 17 publications

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“…6, the highest percentage reduction in IFT is for SW/10 92 SO 4 (-46.55%) and the lowest percentage reduction in IFT is for SW 92 SO 4 (-19.56%). Flock et al (1986) and Karnanda et al (2012) observed similar trend in IFT with increased temperature.…”

Section: Ift Measurements With Temperaturesupporting

confidence: 58%

Selecting a potential smart water for EOR implementation in Asab oil field

Abubacker

Al-Attar

Zekri

et al. 2017

J Petrol Explor Prod Technol

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The IFT and contact angle are believed to have direct impact on wettability alteration of crude oil/water/rock systems. In this work, extensive laboratory work was conducted to investigate the effect of these two key parameters on wettability alteration at elevated temperature (90°C) and ambient conditions. Twenty-six brines representing various scenarios of dilution and sulphate spiking were prepared and tested to identify the smart water most effective in the alteration of wettability. Sea water (SW) was used a base brine. Diluted and sulphate-spiked versions of SW were synthetically prepared following the standard brine preparation procedures. Also standard procedures were followed for the measurement of IFT and contact angle measurements using Teclis tracker. Pendant drop method was implemented to measure the IFT at ambient and 90°C conditions using a special software package that adopts the axisymmetric drop shape analysis and fits the Laplace equation. The same software package was used to take snapshots of oil drops at 90°C, and contact angle was measured manually. The effects of dilution and/or sulphate spiking on the observed IFT and contact angle measurements were investigated using a proposed brine categories-based plotting technique. Natural SW and its sulphate-spiked versions have shown the least oil/brine IFT at ambient and 90°C conditions. The sulphate-spiked SW and its dilutions have resulted in the reduction in oil/brine IFT, whereas the diluted SW showed an increase in oil/brine IFT. Further reduction in IFT was observed at the elevated temperature. SW and SW/50 (50 times diluted sea water) were the only two brines that could yield a contact angle of 113°and 114°, respectively, indicating the change in wettability from oil-wet to the border line of intermediate-wettability conditions. The natural SW that contains 3944 mg/L of sulphate ion has been found to be the most effective in promoting wettability change and thus represents the selected smart water for EOR implementation in Asab oil field. The contact angle measurements were made from the drops formed by the natural drainage process. These measurements are believed to duplicate contact angles in the selected reservoir because of the continuous change in fluids saturation. Keywords

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Section: Ift Measurements With Temperaturesupporting

confidence: 58%

Selecting a potential smart water for EOR implementation in Asab oil field

Abubacker

Al-Attar

Zekri

et al. 2017

J Petrol Explor Prod Technol

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“…When the temperature is higher, the free energy between oil and solution would reduce thus resulting in the enhanced mobility of oil and water and also decreasing the IFT [7]. One more reason is that the increment of temperature can effect on surfactant solution because of the weakening of intermolecular forces at the oil-water interface [8]. From Fig.…”

Section: Effect Of Temperature On Iftmentioning

confidence: 99%

Experiment on Measurement of Interfacial Tension for Subsurface Conditions of Light Oil from Thailand

2017

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Abstract.One of enhanced oil recovery techniques to increase oil production is surfactant flooding. Surfactants are considered as effective chemical agents used in oilfield in Thailand. It is used to reduce the interfacial tension (IFT) of two fluids and to make them flow easier in the reservoir. In this study, Monoethanolamide (MEA) commonly used for carbon dioxide capture, is applied as a surfactant to reduce IFT between oil and brine. Therefore, the aim of this work is to investigate and measure the IFT based on the conditions of subsurface at the oilfield in Thailand. These parameters such as temperature, pressure, salinity as well as the concentration of surfactant are adjusted to investigate the effects on IFT reduction. From the results, it is reported that pressure from 1000 to 2000 psi and temperature varied from 70°C to 90°C can reduce IFT insignificantly. However, salinity and surfactant concentration are the main parameters that impact on the IFT reduction. It can greatly decrease IFT up to 87.13% for surfactant concentration and up to 74.06% for salinity. Finally, the results can be applied to use in the real field for enhanced oil production in Thailand.

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“…Beyond this critical concentration, IFT increases. Karnanda et al (2012) investigated the effect of three surfactants in various concentrations. The results showed that IFT declines sharply with the increase in surfactant concentration.…”

Section: Rock-fluid Interactionsmentioning

confidence: 99%

“…4. Temperature: Karnanda et al (2012) have investigated the effect of temperature on IFT. The results indicated minor temperature effect on IFT measurements with brine solution, purified water, and anionic surfactants; however, the significant effects were seen for solutions of nonionic surfactants.…”

Section: Salt Concentration: Strong Dependency Between Iftmentioning

confidence: 99%

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Evaluation of surfactant flooding using interwell tracer analysis

Khaledialidusti

Kleppe

Enayatpour

2016

J Petrol Explor Prod Technol

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Surfactant flooding is an important enhanced oil recovery (EOR) method, especially in carbonate oil reservoirs where water flooding may not have an effect on oil recovery as much as for sandstone reservoirs. This is because of the initial wettability of most carbonate reservoirs that is mixed-or oil-wet. Since surfactant flooding has a great impact on both fluid-fluid and rock-fluid interactions, it can be an efficient EOR method for these kinds of reservoirs. Surfactants affect fluid-fluid interactions by reducing interfacial tension (IFT) between water and oil phases and rock-fluid interactions by wettability alteration. The objective of this paper is the evaluation of these two surfactant mechanisms in non-fractured carbonate reservoirs using UTCHEM, the University of Texas chemical compositional simulator. In this paper, first, the laboratory data of two surfactant spontaneous imbibition tests for carbonate cores are successfully matched with modeled data to evaluate the mechanisms of surfactant flooding. Second, the field-scale surfactant flooding is simulated using the experimental data from spontaneous imbibition tests. Several cases are modeled in order to study the effect of surfactant flooding in terms of decreasing IFT and wettability alteration. Since the formation brine salinity in most reservoirs is more than the optimum salinity of surfactant phase behavior, the benefit of combining surfactant and low-salinity water is also investigated. Finally, tracer test simulation is performed to estimate the average oil saturation within the swept pore volume at the end of each recovery mode.

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Effect of temperature, pressure, salinity, and surfactant concentration on IFT for surfactant flooding optimization

Cited by 107 publications

References 17 publications

Selecting a potential smart water for EOR implementation in Asab oil field

Selecting a potential smart water for EOR implementation in Asab oil field

Experiment on Measurement of Interfacial Tension for Subsurface Conditions of Light Oil from Thailand

Evaluation of surfactant flooding using interwell tracer analysis

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