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Papers by Ahmed Al-yaseri

Research paper thumbnail of Receding and advancing (CO2+brine+quartz) contact angles as a function of pressure, temperature, surface roughness, salt type and salinity

The Journal of Chemical Thermodynamics, 2016

Research paper thumbnail of Impact of pressure and temperature on CO2-brine-mica contact angles and CO2-brine interfacial tension: Implications for carbon geo-sequestration

Journal of colloid and interface science, Jan 15, 2016

Precise characterization of wettability of CO2-brine-rock system and CO2-brine interfacial tensio... more Precise characterization of wettability of CO2-brine-rock system and CO2-brine interfacial tension at reservoir conditions is essential as they influence capillary sealing efficiency of caprocks, which in turn, impacts the structural and residual trapping during CO2 geo-sequestration. In this context, we have experimentally measured advancing and receding contact angles for brine-CO2-mica system (surface roughness ∼12nm) at different pressures (0.1MPa, 5MPa, 7MPa, 10MPa, 15MPa, 20MPa), temperatures (308K, 323K, and 343K), and salinities (0wt%, 5wt%, 10wt%, 20wt% and 30wt% NaCl). For the same experimental matrix, CO2-brine interfacial tensions have also been measured using the pendant drop technique. The results indicate that both advancing and receding contact angles increase with pressure and salinity, but decrease with temperature. On the contrary, CO2-brine interfacial tension decrease with pressure and increase with temperature. At 20MPa and 308K, the advancing angle is measured...

Research paper thumbnail of CO 2 -wettability of caprocks: Implications for structural storage capacity and containment security

Geophysical Research Letters, 2015

Research paper thumbnail of Influence of temperature and pressure on quartz-water-CO₂ contact angle and CO₂-water interfacial tension

Journal of colloid and interface science, 2015

We measured water-CO2 contact angles on a smooth quartz surface (RMS surface roughness ∼40 nm) as... more We measured water-CO2 contact angles on a smooth quartz surface (RMS surface roughness ∼40 nm) as a function of pressure and temperature. The advancing water contact angle θ was 0° at 0.1 MPa CO2 pressure and all temperatures tested (296-343 K); θ increased significantly with increasing pressure and temperature (θ=35° at 296 K and θ=56° at 343 K at 20 MPa). A larger θ implies less structural and residual trapping and thus lower CO2 storage capacities at higher pressures and temperatures. Furthermore we did not identify any significant influence of CO2-water equilibration on θ. Moreover, we measured the CO2-water interfacial tension γ and found that γ strongly decreased with increasing pressure up to ∼10 MPa, and then decreased with a smaller slope with further increasing pressure. γ also increased with increasing temperature.

Research paper thumbnail of N2+CO2+NaCl brine interfacial tensions and contact angles on quartz at CO2 storage site conditions in the Gippsland basin, Victoria /Australia

Journal of Petroleum Science and Engineering, 2015

Carbon geo-sequestration (CGS) has been identified as an important method to reduce carbon dioxid... more Carbon geo-sequestration (CGS) has been identified as an important method to reduce carbon dioxide (CO 2 ) emissions to the atmosphere thus mitigating global warming. In CGS, the CO 2 captured from large point source emitters is injected into hydrocarbon reservoirs for enhanced oil and gas recovery or into deep saline aquifers for storage.

Research paper thumbnail of Pore-scale analysis of formation damage in Bentheimer sandstone with in-situ NMR and micro-computed tomography experiments

Journal of Petroleum Science and Engineering, 2015

Iglauer, Pore-scale analysis of formation damage in Bentheimer sandstone with in-situ NMR and mic... more Iglauer, Pore-scale analysis of formation damage in Bentheimer sandstone with in-situ NMR and micro-computed tomography experiments, Journal of Petroleum Science and Engineering, http://dx.

Research paper thumbnail of Permeability evolution in sandstone due to injection of CO2-saturated brine or supercritical CO2 at reservoir conditions

Energy Procedia, 2014

We measured the change in permeability of two selected sandstones (Berea, Fonteinebleau) due to i... more We measured the change in permeability of two selected sandstones (Berea, Fonteinebleau) due to injection of CO 2saturated ("live") brine, unsaturated ("dead") brine or supercritical (sc) CO 2 at reservoir conditions. We found that the permeability did not significantly change in a clean sandstone consisting of pure quartz (Fonteinemebleau) due to live or dead brine injection, although permeability changed due to scCO 2 injection by 23%. The permeability in the Berea sandstone, however, changed due to live or dead brine injection, by up to 35%; this permeability reduction in Berea sandstone was likely caused by fines release and subsequent pore throat plugging as the damage was more significant at higher injection rates. We expect that this phenomenon -i.e. rock permeability reduction due to CO 2 injection into the formation -can have a significant and detrimental influence on CO 2 injectivity, which would be reduced accordingly.

Research paper thumbnail of Receding and advancing (CO2+brine+quartz) contact angles as a function of pressure, temperature, surface roughness, salt type and salinity

The Journal of Chemical Thermodynamics, 2016

Research paper thumbnail of Impact of pressure and temperature on CO2-brine-mica contact angles and CO2-brine interfacial tension: Implications for carbon geo-sequestration

Journal of colloid and interface science, Jan 15, 2016

Precise characterization of wettability of CO2-brine-rock system and CO2-brine interfacial tensio... more Precise characterization of wettability of CO2-brine-rock system and CO2-brine interfacial tension at reservoir conditions is essential as they influence capillary sealing efficiency of caprocks, which in turn, impacts the structural and residual trapping during CO2 geo-sequestration. In this context, we have experimentally measured advancing and receding contact angles for brine-CO2-mica system (surface roughness ∼12nm) at different pressures (0.1MPa, 5MPa, 7MPa, 10MPa, 15MPa, 20MPa), temperatures (308K, 323K, and 343K), and salinities (0wt%, 5wt%, 10wt%, 20wt% and 30wt% NaCl). For the same experimental matrix, CO2-brine interfacial tensions have also been measured using the pendant drop technique. The results indicate that both advancing and receding contact angles increase with pressure and salinity, but decrease with temperature. On the contrary, CO2-brine interfacial tension decrease with pressure and increase with temperature. At 20MPa and 308K, the advancing angle is measured...

Research paper thumbnail of CO 2 -wettability of caprocks: Implications for structural storage capacity and containment security

Geophysical Research Letters, 2015

Research paper thumbnail of Influence of temperature and pressure on quartz-water-CO₂ contact angle and CO₂-water interfacial tension

Journal of colloid and interface science, 2015

We measured water-CO2 contact angles on a smooth quartz surface (RMS surface roughness ∼40 nm) as... more We measured water-CO2 contact angles on a smooth quartz surface (RMS surface roughness ∼40 nm) as a function of pressure and temperature. The advancing water contact angle θ was 0° at 0.1 MPa CO2 pressure and all temperatures tested (296-343 K); θ increased significantly with increasing pressure and temperature (θ=35° at 296 K and θ=56° at 343 K at 20 MPa). A larger θ implies less structural and residual trapping and thus lower CO2 storage capacities at higher pressures and temperatures. Furthermore we did not identify any significant influence of CO2-water equilibration on θ. Moreover, we measured the CO2-water interfacial tension γ and found that γ strongly decreased with increasing pressure up to ∼10 MPa, and then decreased with a smaller slope with further increasing pressure. γ also increased with increasing temperature.

Research paper thumbnail of N2+CO2+NaCl brine interfacial tensions and contact angles on quartz at CO2 storage site conditions in the Gippsland basin, Victoria /Australia

Journal of Petroleum Science and Engineering, 2015

Carbon geo-sequestration (CGS) has been identified as an important method to reduce carbon dioxid... more Carbon geo-sequestration (CGS) has been identified as an important method to reduce carbon dioxide (CO 2 ) emissions to the atmosphere thus mitigating global warming. In CGS, the CO 2 captured from large point source emitters is injected into hydrocarbon reservoirs for enhanced oil and gas recovery or into deep saline aquifers for storage.

Research paper thumbnail of Pore-scale analysis of formation damage in Bentheimer sandstone with in-situ NMR and micro-computed tomography experiments

Journal of Petroleum Science and Engineering, 2015

Iglauer, Pore-scale analysis of formation damage in Bentheimer sandstone with in-situ NMR and mic... more Iglauer, Pore-scale analysis of formation damage in Bentheimer sandstone with in-situ NMR and micro-computed tomography experiments, Journal of Petroleum Science and Engineering, http://dx.

Research paper thumbnail of Permeability evolution in sandstone due to injection of CO2-saturated brine or supercritical CO2 at reservoir conditions

Energy Procedia, 2014

We measured the change in permeability of two selected sandstones (Berea, Fonteinebleau) due to i... more We measured the change in permeability of two selected sandstones (Berea, Fonteinebleau) due to injection of CO 2saturated ("live") brine, unsaturated ("dead") brine or supercritical (sc) CO 2 at reservoir conditions. We found that the permeability did not significantly change in a clean sandstone consisting of pure quartz (Fonteinemebleau) due to live or dead brine injection, although permeability changed due to scCO 2 injection by 23%. The permeability in the Berea sandstone, however, changed due to live or dead brine injection, by up to 35%; this permeability reduction in Berea sandstone was likely caused by fines release and subsequent pore throat plugging as the damage was more significant at higher injection rates. We expect that this phenomenon -i.e. rock permeability reduction due to CO 2 injection into the formation -can have a significant and detrimental influence on CO 2 injectivity, which would be reduced accordingly.