Experimental investigation of effect of temperature and pressure on contact angle of four Iranian carbonate oil reservoirs

Najafi‐Marghmaleki, Adel; Barati-Harooni, Ali; Soleymanzadeh, Aboozar; Samadi, Seyed Jamal; Roshani, Babak; Yari, Amir

doi:10.1016/j.petrol.2016.02.004

Cited by 30 publications

(14 citation statements)

References 22 publications

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“…The variations of contact angles within a pressure window of 10–70 MPa are 2.0°, 2.0°, 3.0°, 1.0°, 2.5°, 1.5°, 3.0°, 1.5°, and 1° from panels i–ix of Figure , respectively. In comparison to reported experimental results in other works, , it can be concluded that the surrounding pressure has no discernible effect on the measured contact angles, regardless of the mineral type.…”

Section: Resultssupporting

confidence: 55%

“…Wettability is defined as “the tendency of one fluid to adhere to a solid surface in the presence of other immiscible fluids”. , The knowledge of wettability is very important for many aspects in the petroleum industry, including estimation of oil reserves, prediction of production performance, and implementation of enhanced oil recovery (EOR) methods. , Under oil reservoir conditions, studies of wettability have focused on a crude oil–brine–rock (COBR) system. Changes in the wettability of the rock surface affect the microscopic distribution of formation liquid at the pore scale, which, in turn, affects the displacement process and relative permeability characteristics. − It has been clearly shown that the wettability characteristics of reservoirs depend upon several factors, including oil composition, brine composition, pH, temperature, and pressure. − …”

Section: Introductionmentioning

confidence: 99%

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Investigating the Effect of the Temperature and Pressure on Wettability in Crude Oil–Brine–Rock Systems

et al. 2018

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Wettability is a key parameter that affects the petrophysical properties of reservoir formations. The objective of the present work is to investigate the influence of the temperature and pressure on the wettability in crude oil–brine–rock systems. Using a captive droplet method, the contact angle results of seven minerals and two rock core samples over a range of pressures and temperatures are reported. The data show that raising the pressure from 10 to 70 MPa has no discernible effect on the contact angle, regardless of the mineral type. However, the effect of the temperature on the contact angle depends upon the primary wettability types of the minerals. For water-wet mineral surfaces, the temperature has a notable impact on the measured contact angles (i.e., the contact angle decreases with an increasing temperature), but for neutral-wet or oil-wet samples, the influence of the temperature on the measured contact angles is relatively weak. To explain the behavior of the wettability as a function of the temperature, a mathematical calculation is completed on the basis of the Derjaguin–Landau–Verwey–Overbeek theory. The calculation results show good consistency with the experimental measurements.

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Section: Resultssupporting

confidence: 55%

Section: Introductionmentioning

confidence: 99%

Investigating the Effect of the Temperature and Pressure on Wettability in Crude Oil–Brine–Rock Systems

et al. 2018

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“…The current experimental setup allows measurement of contact angles at low temperature (typically ~2 °C) under vacuum (~650–800 Pa). To determine the relevance of the wettability experiments with respect to in-situ reservoir conditions, previous studies that investigated the effects of temperature and pressure on contact angles were considered 27 – 31 . The observed trends depended on the conditions of the system that was being researched.…”

Section: Discussionmentioning

confidence: 99%

“…For example, Najafi-Marghmaleki et al . 31 studied four different water-wet carbonate oil reservoirs, and noted that varying pressure had no significant effect on the measured contact angle of those reservoirs. However, an increase in temperature changed the wettability of some reservoirs from water-wet to intermediate-wet.…”

Section: Discussionmentioning

confidence: 99%

Live Imaging of Micro-Wettability Experiments Performed for Low-Permeability Oil Reservoirs

Deglint

Clarkson

Debuhr

et al. 2017

Sci Rep

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Low-permeability (unconventional) hydrocarbon reservoirs exhibit a complex nanopore structure and micro (µm) -scale variability in composition which control fluid distribution, displacement and transport processes. Conventional methods for characterizing fluid-rock interaction are however typically performed at a macro (mm) -scale on rock sample surfaces. In this work, innovative methods for the quantification of micro-scale variations in wettability and fluid distribution in a low-permeability oil reservoir was enabled by using an environmental scanning electron microscope. Live imaging of controlled water condensation/evaporation experiments allowed micro-droplet contact angles to be evaluated, while imaging combined with x-ray mapping of cryogenically frozen samples facilitated the evaluation of oil and water micro-droplet contact angles after successive fluid injection. For the first time, live imaging of fluids injected through a micro-injection system has enabled quantification of sessile and dynamic micro-droplet contact angles. Application of these combined methods has revealed dramatic spatial changes in fluid contact angles at the micro-scale, calling into question the applicability of macro-scale observations of fluid-rock interaction.

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“…Captive drop apparatus used pendant drop method for determination of interfacial tension. Numerous researchers applied this technique for measurement of IFT (Flock et al 1986;Hjelmeland and Larrondo 1986;Badakshan and Bakes 1990;Bonfillon et al 1994;Kashefi et al 2016;Lashkarbolooki and Ayatollahi 2016;Najafi-Marghmaleki et al 2016). Captive drop equipment operates in a wide range of temperature (up to 200 °C) and pressure (up to 11,000 psi).…”

Section: Interfacial Tension Measurementmentioning

confidence: 99%

Theoretical and experimental investigation of effect of salinity and asphaltene on IFT of brine and live oil samples

Soleymanzadeh

Rahmati

Yousefi

et al. 2020

J Petrol Explor Prod Technol

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Several factors influence the IFT of oil and formation water. These factors are rooted in the complex composition of oil, presence of different salts in water, water salinity, temperature, and pressure of reservoir. In the first part of this paper, effect of salinity on IFT between brine and an Iranian live oil sample has been studied experimentally. It is observed that IFT increases almost linearly with brine concentration. Also, linear increasing behavior of IFT with respect to pressure is obviously seen. Then, using thermodynamic properties such as surface excess concentration, chemical potential, chemical activity, and activity coefficient, results were analyzed and observed effect of salinity and pressure were justified thermodynamically. In the second part, the effect of asphaltene on IFT reduction has been studied. In previous works, the investigators extracted resin and asphaltene and then examined their effects on IFT in the absence of other fractions of oil phase. We believe that all fractions play a role in this phenomenon so, in this paper, the effect of natural surfactants of oil phase on IFT has been investigated in presence of all fractions of oil. Hence, SARA test was performed on all samples. Then, IFT between oil samples and brine were measured using captive drop instrument at 25 °C and 3000 psia. Results showed that neither asphaltene content nor asphaltene/resin ratio is a good indicator for effect of asphaltene on IFT, whereas colloidal instability index could be a useful tool to predict asphaltene effect on IFT.

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Experimental investigation of effect of temperature and pressure on contact angle of four Iranian carbonate oil reservoirs

Cited by 30 publications

References 22 publications

Investigating the Effect of the Temperature and Pressure on Wettability in Crude Oil–Brine–Rock Systems

Investigating the Effect of the Temperature and Pressure on Wettability in Crude Oil–Brine–Rock Systems

Live Imaging of Micro-Wettability Experiments Performed for Low-Permeability Oil Reservoirs

Theoretical and experimental investigation of effect of salinity and asphaltene on IFT of brine and live oil samples

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