Prediction of live reservoir fluid interfacial tension from dead oil measurements

Hamad, Mohammed Al; Sauerer, Bastian; Okasha, Taha; Abdallah, Wael

doi:10.1016/j.petrol.2020.108000

Cited by 8 publications

(2 citation statements)

References 32 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Variations of IFT with pressure are generally affected by the light ends in crude oil . Al Hamad et al noticed a general IFT increase from dead oil at ambient conditions to live oil at increased pressures . Pressure rise intensifies the interactions between molecules at the oil–water interface and reduces the distance between molecules.…”

Section: Resultsmentioning

confidence: 99%

“…35 Al Hamad et al noticed a general IFT increase from dead oil at ambient conditions to live oil at increased pressures. 39 Pressure rise intensifies the interactions between molecules at the oil−water interface and reduces the distance between molecules. High pressures can eliminate the effects of ions by repelling the cations from the oil/water interface, which might alter the solubility of the oil species at the interface 37 and thus increase the IFT.…”

Section: Resultsmentioning

confidence: 99%

See 1 more Smart Citation

Improved Oil Recovery in Carbonate Cores Using Alumina Nanoparticles

et al. 2023

View full text Add to dashboard Cite

The purpose of this research is to investigate the use of alumina nanoparticles (NPs) in low-salinity brine for enhanced oil recovery in carbonate oil reservoirs. A set of analyses including oil/water interfacial tension (IFT), zeta potential, and rock wettability were performed to choose optimized dispersions for spontaneous imbibition tests. The highest oil/water IFT reduction by 0.3% w/v brine occurred at 80 °C/14.5 psi (from 41.3 to 24.3 mN/m at ambient conditions), whereas upon adding 0.05 wt % alumina, IFT declined to 15.6 mN/m at 60 °C/14.5 psi, implying the dependency of NP performance on thermodynamics. The adsorption energy of 0.05 wt % alumina in low-salinity brine at varying pressures/temperatures was calculated to be 6844 k B T at 60 °C/14.5 psi and 5753 k B T at 25 °C/600 psi, confirming that temperature is a more influential parameter than pressure. The wettability analysis revealed a considerable reduction in contact angle from 151 to 65 ± 5° using 0.03–0.05 wt % alumina in low-salinity brine, whereas the reduction by low-salinity brine alone was much smaller. Ion chromatography of core effluents showed no natural presence of anhydrite in the rock texture but sulfate adsorbed to the rock surface during Na2SO4 flooding, showing the interaction of sulfate-rich brines with rock Ca2+, which was also recognized by zeta potential measurements (rock zeta potential shifts from positive toward negative on adding ions, which implies the formation of > CaSO4 –). Spontaneous imbibition results showed that adding alumina to sulfate-containing low-salinity brine in the tertiary stage can double the oil production in a shorter time as compared to low-salinity brine alone, proving a synergistic effect with alumina NPs.

show abstract

Section: Resultsmentioning

confidence: 99%

Section: Resultsmentioning

confidence: 99%