Analysis of the Wettability Alteration Process during Seawater Imbibition into Preferentially Oil-Wet Chalk Cores

Yu, Liping; Evje, Steinar; Kleppe, Hans; Kårstad, T.; Fjelde, Ingebret; Skjæveland, S.M.

doi:10.2118/113304-ms

Cited by 13 publications

(12 citation statements)

References 27 publications

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“…Reservoir modelling is a very valuable tool, as it helps to verify and validate the experimental LSW results to predicts wettability process at reservoir conditions (high temperature and pressure), where experimental work may not be possible. Yu et al [183] developed a numerical model to simulate dynamic wettability of oil-wet chalk cores, taking into account molecular diffusion, adsorption of a wettability modifier agent (SO 2− 4 ions), gravity, and capillary pressure. The correlation between capillary pressure and relative permeability and its influence on wettability alteration was calculated by interpolation.…”

Section: Reservoir Modellingmentioning

confidence: 99%

Low Salinity Waterflooding in Carbonate Reservoirs: Review of Interfacial Mechanisms

Derkani

Fletcher

Abdallah

et al. 2018

Colloids and Interfaces

159

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Carbonate rock reservoirs comprise approximately 60% of the world's oil and gas reserves. Complex flow mechanisms and strong adsorption of crude oil on carbonate formation surfaces can reduce hydrocarbon recovery of an oil-wet carbonate reservoir to as low as 10%. Low salinity waterflooding (LSW) has been confirmed as a promising technique to improve the oil recovery factor. However, the principal mechanism underpinning this recovery method is not fully understood, which poses a challenge toward designing the optimal salinity and ionic composition of any injection solution. In general, it is believed that there is more than one mechanism involved in LSW of carbonates; even though wettability alteration toward a more desirable state for oil to be recovered could be the main cause during LSW, how this alteration happens is still the subject of debate. This paper reviews different working conditions of LSW, previous studies, and field observations, alongside the proposed interfacial mechanisms which affect the colloidal interactions at oil-rock-brine interfaces. This paper provides a comprehensive review of studies on LSW in carbonate formation and further analyzes the latest achievements of LSW application in carbonates, which helps to better understand the challenges involved in these complicated multicomponent systems and potentially benefits the oil production industry.

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Section: Reservoir Modellingmentioning

confidence: 99%

Low Salinity Waterflooding in Carbonate Reservoirs: Review of Interfacial Mechanisms

Derkani

Fletcher

Abdallah

et al. 2018

Colloids and Interfaces

159

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“…For original wetting condition, reduction of interfacial tension will lead to a reduction of the capillary pressure within the pores and/or deformation of trapped oil. However, when wettability reversal to water-wet condition is the main mechanism for enhancing oil recovery, reduction of interfacial tension and consequently capillary pressure negatively influences the imbibition of water into small pores (Yu et al 2008). In fact, after wettability alteration to water-wet condition, higher capillary pressure will lead to a stronger imbibition of water into small pores and consequently higher oil recovery.…”

Section: Interfacial Tensionmentioning

confidence: 99%

“…In the case of small pores, capillary pressure hinders entrance of wetting phase into pores. However, when Nanoparticles are adsorbed on surface of pore throat, alteration of rock wettability to water-wet condition reverse the direction of capillary force and cause strong imbibition of wetting phase into small pores and depleted them (Yu et al 2008).…”

Section: Mechanismmentioning

confidence: 99%

Experimental investigation of SiO2 nanoparticles on enhanced oil recovery of carbonate reservoirs

Roustaei¹,

Bagherzadeh²

2014

J Petrol Explor Prod Technol

189

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Wettability alteration is an important method to increase oil recovery from oil-wet carbonate reservoirs. Chemical agents are used as wettability modifiers in carbonate systems; however, the role of Nanoparticles in this field is still in its infancy and consequently has attracted the attention of many researchers in the last decade. In this work, the impact of SiO 2 Nanoparticles on the wettability of a carbonate reservoir rock was experimentally studied. The impact of these Nanoparticles on the wettability of carbonate systems is still in its infancy. For this purpose, the effect of Nanofluid's concentration on wettability and interfacial tension were investigated to determine the optimum concentration of Nanofluid for injection into core samples. The result suggests that a concentration of 4 g/L of Nanofluid could significantly alter the wettability of the rock from a strongly oil-wet to a strongly water-wet condition. Moreover, we studied the Nanofluids' potential in enhanced oil recovery of oil-wet core plugs. The results show that a considerable amount of oil can be recovered right after start of water injection to the aged core plug with Nano fluid.

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“…water-wet conditions before any oil migration, the decrease of IFT will induce a decrease in capillary pressure in the pores which results in the mobilization of both the trapped and residual oil. With an extreme change in wettability such as in the wettability reversal of a reservoir to a water-wet condition, a central process of EOR, an increase in IFT will lead to increasing capillary pressures that will result in an increased wettability of the pores, and a strong imbibition of the wetting phase into the small pores which will thus enhance the oil recovery (Yu et al 2008). In our study on the effects of SiO 2 nanoparticles on IFT of brine-surfactant-crude oil systems, we determined that these nanoparticles either Appl Nanosci (2017) 7:947-972 965 decrease IFT, increase IFT, or exhibit no affect at all.…”

Section: Raspberry-like Morphology Of Sio 2 Nanoparticlesmentioning

confidence: 99%

Effects of silica-based nanostructures with raspberry-like morphology and surfactant on the interfacial behavior of light, medium, and heavy crude oils at oil-aqueous interfaces

Bai

Korte

et al. 2017

Appl Nanosci

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Any efficient exploitation of new petroleum reservoirs necessitates developing methods to mobilize the crude oils from such reservoirs. Here silicon dioxide nanoparticles (SiO 2 NPs) were used to improve the efficiency of the chemical-enhanced oil recovery process that uses surfactant flooding. Specifically, SiO 2 NPs (i.e., 0, 0.001, 0.005, 0.01, 0.05, and 0.1 wt%) and Tween Ò 20, a nonionic surfactant, at 0, 0.5, and 2 critical micelle concentration (CMC) were varied to determine their effect on the stability of nanofluids and the interfacial tension (IFT) at the oil-aqueous interface for 5 wt% brine-surfactantSiO 2 nanofluid-oil systems for West Texas Intermediate light crude oil, Prudhoe Bay medium crude oil, and Lloydminster heavy crude oil. Our study demonstrates that SiO 2 NPs may either decrease, increase the IFT of the brinesurfactant-oil systems, or exhibit no effects at all. For the brine-surfactant-oil systems, the constituents of the oil and aqueous substances affected the IFT behavior, with the nanoparticles causing a contrast in IFT trends according to the type of crude oil. For the light oil system (0.5 and 2 CMC Tween threshold concentration resulted in a decrease in IFT, and concentrations above this threshold resulted in an increase in IFT. The IFT decreased until the NP concentration reached a threshold concentration where synergetic effects between nonionic surfactants and SiO 2 NPs are the opposite and result in antagonistic effects. Adsorption of both SiO 2 NPs and surfactants at an interface caused a synergistic effect and an increased reduction in IFT. The effectiveness of the brine-surfactant-SiO 2 nanofluids in decreasing the IFT between the oil-aqueous phase for the three tested crude oils were ranked as follows: (1) Prudhoe Bay [ (2) Lloydminster [ and (3) West Texas Intermediate. The level of asphaltenes and resins in these crude oil samples reflected these rankings. A decrease in the IFT also indicated the potential of the SiO 2 NPs to decrease capillary pressure and induce the movement and recovery of oil in original water-wet reservoirs. Conversely, an increase in IFT indicated the potential of SiO 2 NPs to increase capillary pressure and oil recovery in reservoirs subject to wettability reversal under water-wet conditions. Raspberrylike morphology particles were discovered in 5 wt% brinesurfactant-SiO 2 nanofluid-oil systems. The development of raspberry-like particles material with high surface area, high salt stability, and high capability of interfaces alteration and therefore wettability changes offers a wide range of applications in the fields of applied nanoscience, environmental engineering, and petroleum engineering.

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Analysis of the Wettability Alteration Process during Seawater Imbibition into Preferentially Oil-Wet Chalk Cores

Cited by 13 publications

References 27 publications

Low Salinity Waterflooding in Carbonate Reservoirs: Review of Interfacial Mechanisms

Low Salinity Waterflooding in Carbonate Reservoirs: Review of Interfacial Mechanisms

Experimental investigation of SiO2 nanoparticles on enhanced oil recovery of carbonate reservoirs

Effects of silica-based nanostructures with raspberry-like morphology and surfactant on the interfacial behavior of light, medium, and heavy crude oils at oil-aqueous interfaces

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