Wettability alteration and oil recovery by water imbibition at elevated temperatures

Schembre, J.M.; Tang, Guiqian; Kovscek, Anthony R.

doi:10.1016/j.petrol.2006.03.017

Cited by 156 publications

(75 citation statements)

References 37 publications

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“…Therefore, wettability alteration occurs with more speed at higher temperatures compared with lower temperature conditions (Shehata and Nasr El-Din 2015). Furthermore, Schembre et al (2006) found that temperature changed the recovery factor from 12% to 43% in spontaneous imbibition tests. In this study, flooding was performed after imbibition tests on the same core samples at different temperatures.…”

Section: Introductionmentioning

confidence: 95%

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Enhanced oil recovery from carbonate reservoirs by spontaneous imbibition of low salinity water

et al. 2018

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An experimental study was performed to investigate the impact of low salinity water on wettability alteration in carbonate core samples from southern Iranian reservoirs by spontaneous imbibition. In this paper, the effect of temperature, salinity, permeability and connate water were investigated by comparing the produced hydrocarbon curves. Contact angle measurements were taken to confirm the alteration of surface wettability of porous media. Oil recovery was enhanced by increasing the dilution ratio of sea water, and there existed an optimum dilution ratio at which the highest oil recovery was achieved. In addition, temperature had a very significant impact on oil recovery from carbonate rocks. Furthermore, oil recovery from a spontaneous imbibition process was directly proportional to the permeability of the core samples. The presence of connate water saturation inside the porous media facilitated oil production significantly. Also, the oil recovery from porous media was highly dependent on ion repulsion/attraction activity of the rock surface which directly impacts on the wettability conditions. Finally, the highest ion attraction percentage was measured for sodium while there was no significant change in pH for all experiments.

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Section: Introductionmentioning

confidence: 95%

“…Experimental results confirmed the important role of temperature in recovering oil from core samples and a significant increase in wettability indices at higher temperatures. In addition, the impact of initial wettability conditions on oil recovery has been investigated (Schembre et al 2006).…”

Section: Introductionmentioning

confidence: 99%

Enhanced oil recovery from carbonate reservoirs by spontaneous imbibition of low salinity water

et al. 2018

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“…The increase of the oil recovery may be due to the increase of the oil mobility and fluid expansion. Oil recovery by spontaneous imbibition shows an increasing trend with temperature (Tang and Morrow [5][6], Schembre et al [8], Hamouda and Rezaei Gomari [9], and Karoussi and Hamouda [14]). Wettability alteration is not a direct option in Eclipse simulator; Delshad et al [18] adapted a chemical flooding simulator to include wettability alteration process.…”

Section: Simulation Of Oil Recovery: Temperature Effectmentioning

confidence: 99%

“…Al-Hadhrami and Blunt [7] in a field case study showed that at a transition temperature chalky limestone rock would undergo through a wettability reversal process from oil-wet to water-wet with temperature. Schembre et al [8] also correlated the improvement in oil recovery from diatomaceous rock to the alteration of wettability at elevated temperature by renewal of surfaces.…”

Section: Introductionmentioning

confidence: 98%

Effect of Temperature, Wettability and Relative Permeability on Oil Recovery from Oil-wet Chalk

Hamouda

Karoussi

2008

Energies

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It is customary, for convenience, to use relative permeability data produced at room temperature. This paper shows that this practice underestimates oil recovery rates and ultimate recovery from chalk rocks for high temperature reservoirs. Above a certain temperature (80°C in this work) a reduction of oil recovery was observed. The reduction in oil recovery is reflected by the shift of relative permeability data towards more oil-wet at high temperature (tested here 130°C). However, both IFT and contact angle measurements indicate an increase in water wetness as temperature increases, which contradict the results obtained by relative permeability experiments. This phenomenon may be explained based on the total interaction potential, which basically consists of van der Waals attractive and short-range Born repulsive and double layer electrostatic forces. The fluid/rock interactions is shown to be dominated by the repulsive forces above 80°C, hence increase fine detachment enhancing oil trapping. In other words the indicated oil wetness by relative permeability is misleading.

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“…Rock wettability can be assessed by several techniques and indexes. In the lab duties, static spontaneous imbibition experiments (Høgnesen et al 2006; Karimaie et al 2006;Schembre et al 2006) and qualitative indicators combining with different core flooding tests which render quantitative indexes for wettability. Such indexes vary with the physicochemical properties of the fluids used (Alotaibi and Nars-El-Din 2009;Al-Maamari and Buckley 2000) and the rock properties.…”

Section: Introductionmentioning

confidence: 99%

Oil recovery and wettability alteration in carbonates due to carbonate water injection

Ruidiaz

Winter

Trevisan

2017

J Petrol Explor Prod Technol

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Enhanced oil recovery in carbonates due to wettability alteration has received much attention recently. In contrast to sandstones reservoirs, carbonates are neutralwet or preferentially oil-wet. The use of CO 2 dissolved into water has emerged as an alternative method for EOR operations in carbonates reservoirs. In the present paper, oil recovery from two carbonate outcrop rocks was evaluated with different brines containing CO 2 . The evaluation included a qualitative approach by spontaneous imbibition tests and a quantitative assessment by the Amott-Harvey index. The rocks tested were limestone and dolomite samples known as analogous to Brazilian pre-salt reservoirs. The testing fluids were a medium gravity crude oil, seawater concentration brine, formation equivalent brine and the carbonated version of these brines. Results shown additional oil recovery directly associated with wettability alteration driven by brine concentration switches. Oil recovery increases were observed independently if the brine concentration decreased or increased over the water replacement process. Wettability alteration took place in both carbonate types starting at oil-wet to neutral-wet conditions. Similar tests carried out with equivalent carbonated brines showed similar alterations in the wetting properties, trending no dependence on salt concentration. However, CO 2 and its derived ions dissolved in the brines seem to inhibit the wettability alteration mechanism.

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Wettability alteration and oil recovery by water imbibition at elevated temperatures

Cited by 156 publications

References 37 publications

Enhanced oil recovery from carbonate reservoirs by spontaneous imbibition of low salinity water

Enhanced oil recovery from carbonate reservoirs by spontaneous imbibition of low salinity water

Effect of Temperature, Wettability and Relative Permeability on Oil Recovery from Oil-wet Chalk

Oil recovery and wettability alteration in carbonates due to carbonate water injection

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