ORCID Profile
0000-0001-9094-1258
Current Organisations
Edith Cowan University
,
King Fahd University of Petroleum and Minerals
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Publisher: MDPI AG
Date: 05-09-2021
DOI: 10.3390/EN14175542
Abstract: Wettability is one of the main parameters controlling CO2 injectivity and the movement of CO2 plume during geological CO2 sequestration. Despite significant research efforts, there is still a high uncertainty associated with the wettability of CO2/brine/rock systems and how they evolve with CO2 exposure. This study, therefore, aims to measure the contact angle of sandstone s les with varying clay content before and after laboratory core flooding at different reservoir pressures, of 10 MPa and 15 MPa, and a temperature of 323 K. The s les’ microstructural changes are also assessed to investigate any potential alteration in the s les’ structure due to carbonated water exposure. The results show that the advancing and receding contact angles increased with the increasing pressure for both the Berea and Bandera Gray s les. Moreover, the results indicate that Bandera Gray sandstone has a higher contact angle. The sandstones also turn slightly more hydrophobic after core flooding, indicating that the sandstones become more CO2-wet after CO2 injection. These results suggest that CO2 flooding leads to an increase in the CO2-wettability of sandstone, and thus an increase in vertical CO2 plume migration and solubility trapping, and a reduction in the residual trapping capacity, especially when extrapolated to more prolonged field-scale injection and exposure times.
Publisher: Elsevier BV
Date: 2014
Publisher: Elsevier BV
Date: 02-2020
Publisher: American Chemical Society (ACS)
Date: 28-03-2023
Publisher: American Chemical Society (ACS)
Date: 06-09-2023
Publisher: Elsevier BV
Date: 03-2015
DOI: 10.1016/J.JCIS.2014.11.010
Abstract: 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.
Publisher: Elsevier BV
Date: 10-2023
Publisher: American Geophysical Union (AGU)
Date: 24-05-2021
DOI: 10.1029/2021GL092976
Abstract: Hydrogen is a clean fuel that can potentially revolutionize the energy supply chain and decarbonize fuel consumption. However, a key hurdle that needs to be overcome before a full‐scale hydrogen economy can be established is hydrogen storage which is currently the main limitation. Here, we propose that hydrogen gas can be stored in underground coal seams, where it adsorbs on the coal surface. However, currently, no hard data related to such a procedure exists. We, therefore, demonstrate experimentally that significant amounts of hydrogen gas can be stored via this route. Hydrogen adsorption capacities reached 0.6 moles H 2 /kg of coal at 14.3 MPa, and adsorption capacity initially increased strongly with pressure (up to ∼4 MPa) and then plateaued out, while temperature only had a very minor influence. This study provides fundamental data for hydrogen storage in coal seams, and thus aids in the industrial implementation of a hydrogen supply chain.
Publisher: Elsevier BV
Date: 11-2021
Publisher: Elsevier BV
Date: 04-2021
Publisher: Elsevier BV
Date: 11-2022
Publisher: Elsevier BV
Date: 02-2022
Publisher: Elsevier BV
Date: 08-2018
DOI: 10.1016/J.JCIS.2018.04.029
Abstract: Wettability plays an important role in underground geological storage of carbon dioxide because the fluid flow and distribution mechanism within porous media is controlled by this phenomenon. CO We measured the contact angle of deionised water and brine/CO The measured contact angle of sandstone was systematically greater than that of pure quartz because of the pores present in sandstone. Moreover, the effect of pressure and temperature on the contact angle of sandstone was similar to that of pure quartz. The results showed that the contact angle increases with increase in temperature and pressure and decreases with increase in salinity.
Publisher: EDP Sciences
Date: 2023
DOI: 10.1051/E3SCONF/202336601008
Abstract: In-situ nuclear magnetic resonance (NMR) core flooding system has enabled researchers to monitor several rock properties such as porosity, pore size distribution, and fluid saturation along the tested s les with high resolutions and under reservoir conditions. However, spatially resolved rock strength/mechanical property alteration coupled to fluid migration/substitution remains poorly characterized. To this end, Fiber Bragg Grating (FBG) multiplex sensors were integrated with NMR core flooding system to monitor rock strength changes, or generally speaking, to observe hydro-mechanical-chemical coupling mechanisms during core flooding tests. In this study, we present a novel approach on how to conduct core flooding experiments, while simultaneously monitoring NMR and FBG strain response of the tested limestone plug. The NMR cell was modified to integrate FBG technology without impeding the NMR signal and core flooding high pressure/temperature capacity. A high spatial resolution optical fiber was attached onto the s le radial surface. The results show the successful association of NMR and FBG sensors to track any change at each stage of brine injection. The FBG is capable of measuring the rock strain variations induced by rock-fluid interactions during brine injection, allowing it to capture the fluid front location along with the s le and at a faster rate than the NMR.
Publisher: Elsevier BV
Date: 09-2021
Publisher: American Geophysical Union (AGU)
Date: 06-11-2015
DOI: 10.1002/2015GL065787
Publisher: American Geophysical Union (AGU)
Date: 28-04-2016
DOI: 10.1002/2016GL068278
Publisher: Elsevier BV
Date: 08-2022
Publisher: Elsevier BV
Date: 02-2024
Publisher: American Chemical Society (ACS)
Date: 09-05-2017
Publisher: Elsevier BV
Date: 02-2023
Publisher: Elsevier BV
Date: 06-2022
Publisher: Elsevier BV
Date: 10-2021
Publisher: American Society of Civil Engineers (ASCE)
Date: 02-2018
Publisher: Elsevier BV
Date: 03-2018
Publisher: American Chemical Society (ACS)
Date: 12-2018
Publisher: Elsevier BV
Date: 07-2020
Publisher: Elsevier BV
Date: 10-2021
Publisher: Elsevier BV
Date: 06-2023
Publisher: American Chemical Society (ACS)
Date: 21-03-2023
Publisher: Elsevier BV
Date: 11-2020
Publisher: Elsevier BV
Date: 02-2022
Publisher: Elsevier BV
Date: 09-2021
Publisher: American Chemical Society (ACS)
Date: 03-08-2020
Publisher: Elsevier BV
Date: 12-2022
Publisher: Elsevier BV
Date: 12-2021
Publisher: Elsevier BV
Date: 09-2021
Publisher: American Chemical Society (ACS)
Date: 05-08-2020
Publisher: Elsevier BV
Date: 03-2018
Publisher: MDPI AG
Date: 10-08-2022
DOI: 10.3390/MA15165485
Abstract: Wettability has been the focal point of many studies in metal oxide materials due to their applications in water–gas shift reactions, organic reactions, thermochemical water splitting, and photocatalysis. This paper presents the results of systematic experimental studies on the wettability of surfaces of nanostructured transition-metal oxides (TMOs) (Al2O3, CeO2, and AlCeO3). The wettability of nanoparticles was investigated by measuring contact angles of different concentrations of water-based nanofluids (0.05–0.1 wt%) on the glass slide. The morphology, the heterostructure, and the nature of incorporated nanoparticles were confirmed by scanning electron microscopy (SEM) and transmission electron microscopy (TEM). Characteristic diffraction patterns of the nanomaterials were evaluated using energy-dispersive X-ray spectroscopy (EDS) and X-ray diffraction (XRD) techniques. The contact angles of water–Al2O3, water–CeO2, and water–AlCeO3 were measured as 77.5 ± 5°, 89.8 ± 4°, and 69.2 ± 1°, respectively. This study suggests that AlCeO3 is strongly water-wet (hydrophilic), while CeO2 is weakly water-wet (hydrophobic). It further demonstrated that the sizes and compositions of the nanoparticles are key parameters that influence their wetting behaviors.
Publisher: Elsevier BV
Date: 08-2016
DOI: 10.1016/J.JCIS.2016.04.041
Abstract: The low recovery of hydraulic fracturing fluid in unconventional shale reservoirs has been in the centre of attention from both technical and environmental perspectives in the last decade. One explanation for the loss of hydraulic fracturing fluid is fluid uptake by the shale matrix where capillarity is the dominant process controlling this uptake. Detailed understanding of the rock wettability is thus an essential step in analysis of loss of the hydraulic fracturing fluid in shale reservoirs, especially at reservoir conditions. We therefore performed a suit of contact angle measurements on a shale s le with oil and aqueous ionic solutions, and tested the influence of different ion types (NaCl, KCl, MgCl2, CaCl2), concentrations (0.1, 0.5 and 1M), pressures (0.1, 10 and 20MPa) and temperatures (35 and 70°C). Furthermore, a physical model was developed based on the diffuse double layer theory to provide a framework for the observed experimental data. Our results show that the water contact angle for bivalent ions is larger than for monovalent ions and that the contact angle (of both oil and different aqueous ionic solutions) increases with increase in pressure and/or temperature these increases are more pronounced at higher ionic concentrations. Finally, the developed model correctly predicted the influence of each tested variable on contact angle. Knowing contact angle and therefore wettability, the contribution of the capillary process in terms of water uptake into shale rocks and the possible impairment of hydrocarbon production due to such uptake can be quantified.
Publisher: American Chemical Society (ACS)
Date: 12-2021
Publisher: American Chemical Society (ACS)
Date: 22-09-2023
Publisher: Elsevier BV
Date: 10-2021
Publisher: Elsevier BV
Date: 12-2021
Publisher: Elsevier BV
Date: 12-2021
Publisher: Elsevier BV
Date: 10-2021
Publisher: American Chemical Society (ACS)
Date: 21-06-2023
Publisher: American Chemical Society (ACS)
Date: 11-01-2022
Publisher: Elsevier BV
Date: 04-2018
Publisher: Elsevier BV
Date: 05-2015
Publisher: American Chemical Society (ACS)
Date: 24-03-2023
Publisher: American Chemical Society (ACS)
Date: 29-03-2020
Publisher: American Chemical Society (ACS)
Date: 14-04-2021
Publisher: Yandy Scientific Press
Date: 06-07-2021
Publisher: Elsevier BV
Date: 04-2021
Publisher: Elsevier BV
Date: 10-2021
Publisher: Elsevier BV
Date: 12-2023
Publisher: Elsevier BV
Date: 05-2022
Publisher: Springer Science and Business Media LLC
Date: 07-01-2021
DOI: 10.1007/S13202-020-01081-2
Abstract: Fracture is one of the most important geological phenomena that affect the production of hydrocarbon compounds in broken carbonate reservoirs. However, fracture controlling factors must be combined with well data to achieve accurate fracture modeling. Therefore, structural data, drilling data, well flow diagrams, cores data, wells production data, and dynamic reservoir data have been considered here. Finally, by combining the above-mentioned information and through statistical and mathematical methods, the mechanism of fracture creation, general trends, and dominant fracture patterns are determined. These patterns are directly related to the tectonic regime and the stresses governing the region. For the first time, in this paper, we ided Zubair carbonate gas reservoir into 10 zones based on porosity and water saturation, and shale volume variation. We conclude that just four-zone of these are economic producible. Besides, the dominant lithology of this formation is more than limestone and a small number of thin shale layers. We defined types of cross-sectional petro-physical graphs and confirmed them by the geological graphic diagram prepared at the head.
Publisher: Wiley
Date: 13-12-2022
DOI: 10.1002/APP.52037
Abstract: Excessive water production from natural reservoirs is a major challenge in oil and gas industry. Relative permeability modifiers (RPM) are used to selectively reduce water production with minimum effect on the hydrocarbon production. This work examined the performance of polyacrylamide in terms of its water control efficiency at prolonged water‐gas flowing cycles. During each cycle, as the volume of injected water increased, the RPM demonstrated stronger performance in terms of reducing water permeability. This is attributed to the swelling of polymer layer adsorbed to the pore surfaces. Conversely, during each cycle, higher volume of gas injection led to less reduction in the gas effective permeability ( PR g ) which is due to polymer shrinkage. The reduction in water absolute permeability ( PR w ) of the treated micromodel in each injection cycle was significantly greater than the reduction in gas permeability. Interestingly, as water‐gas cycles progressed, a significant increase in water permeability reduction was observed. It is also found that polymer expansion and shrinkage are reversible. As such, the RPM performance depends on the injected fluid, injected fluid volumes and water‐gas injecting cycling. We thus conclude that that polymer swelling, and shrinkage and polymer‐gas interaction play a vital role in RPM performance.
Publisher: Elsevier BV
Date: 07-2023
Publisher: Elsevier BV
Date: 05-2015
Publisher: Elsevier BV
Date: 07-2022
Publisher: American Chemical Society (ACS)
Date: 07-11-2017
Publisher: Elsevier BV
Date: 11-2023
Publisher: Elsevier BV
Date: 2022
Publisher: Elsevier BV
Date: 02-2016
Publisher: Elsevier BV
Date: 2016
DOI: 10.1016/J.JCIS.2015.09.076
Abstract: 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 to be ∼110°, indicating CO2-wetting. The results have been compared with various published literature data and probable factors responsible for deviations have been highlighted. Finally we demonstrate the implications of measured data by evaluating CO2 storage heights under various operating conditions. We conclude that for a given storage depth, reservoirs with lower pressures and high temperatures can store larger volumes and thus exhibit better sealing efficiency.
Publisher: Springer Science and Business Media LLC
Date: 15-02-2022
DOI: 10.1007/S13202-022-01465-6
Abstract: A benchtop humidity and temperature chamber was used to assess water vapor sorption in four US shale s les at 90 °C. Water sorption isotherms were measured at relative humidity ranging from 10 to 99% and temperature of 90 °C. Shale fractal properties were then evaluated, and capillary pressure (ranging from 1.70 to 386 MPa) was obtained using Kelvin relationship. The results show that Mancos shale, from the US, adsorbed more absorbed water due to its high clay concentration and low TOC. However, Wolfc shale, from the US, has the lowest TOC and clay concentration, adsorbing the lowest amount of water. There is little hysteresis between adsorption and desorption isotherms explaining water retention phenomenon in some shales. The obtained fractal dimension values ranged between 2.45 and 2.76 and average of 2.56 indicating irregular pore surface and complex pore structure. All shale s le's capillary curves were fitted to Brooks & Corey and van Genuchten models with nonlinear regression. The fitting coefficient, R 2 , which represents the proportion of variance for Brooks & Corey fits ranged from 0.90 to 0.97 for imbibition and 0.85 to 0.98 for drainage, while R 2 for the van Genuchten model ranged from 0.94 to 0.99 for both imbibition and drainage. Thus, the proposed method can be used to measure capillary pressure–saturation relationships in gas shales.
Publisher: Elsevier BV
Date: 2024
Publisher: Elsevier BV
Date: 04-2018
Publisher: American Chemical Society (ACS)
Date: 30-07-2021
Publisher: Elsevier BV
Date: 05-2021
Publisher: Elsevier BV
Date: 11-2022
Publisher: Elsevier BV
Date: 12-2021
Publisher: Elsevier BV
Date: 08-2023
Publisher: Wiley
Date: 28-06-2016
Publisher: Elsevier BV
Date: 11-2022
Publisher: American Chemical Society (ACS)
Date: 24-10-2017
Publisher: Elsevier BV
Date: 11-2022
Publisher: Elsevier BV
Date: 10-2021
Publisher: Elsevier BV
Date: 10-2022
Publisher: Elsevier BV
Date: 06-2022
Publisher: American Chemical Society (ACS)
Date: 06-06-2023
Publisher: Springer Science and Business Media LLC
Date: 04-07-2022
DOI: 10.1007/S13202-022-01533-X
Abstract: Acidizing is one of the most used stimulation techniques in the petroleum industry. Several reports have been issued on the difficulties encountered during the stimulation operation of the Ahdeb oil field, particularly in the development of the Mishrif reservoir, including the following: (1) high injection pressures make it difficult to inject acid into the reservoir formation, and (2) only a few acid jobs have been effective in Ahdeb oil wells, while the bulk of the others has been unsuccessful. The significant failure rate of oil well stimulation in this deposit necessitates more investigations. Thus, we carried out this experimental study to systematically investigate the influence of acid treatment on the geomechanical properties of Mi4 formation of the Mishrif reservoir. The acid core-flood experiments were performed on seven core s les from the oil reservoir in central Iraq. The porosity, permeability, acoustic velocities, rock strength, and dynamic elastic parameters were computed before and after the acidizing treatment. To determine the optimal acid injection rate, different injection flow rates were used in the core-flooding experiments. The propagation of an acid-induced wormhole and its effect on the rock properties were analyzed and compared to that of intact rocks. Computed tomography (CT) scan and a 3D reconstruction technique were also conducted to establish the size and geometry of the generated wormhole. To analyze the influence of mineralogical variation and heterogeneity and confirm the consistency of the outcomes, acidizing experiments on different rock s les were conducted. The results demonstrate that for all the rock s les studied, the mechanical properties exhibit rock weakening post-acid treatment. The Young’s modulus reduced by 26% to 37%, while the Poisson’s ratio, the coefficient of lateral earth pressure at rest, and the material index increased by 13% to 20%, 23% to 32%, and 28% to 125%, respectively. The CT scan visually confirmed that the acid treatment effectively creates a pathway for fluid flow through the core.
Publisher: Elsevier BV
Date: 2023
Publisher: American Chemical Society (ACS)
Date: 24-06-2022
Publisher: Wiley
Date: 28-08-2021
DOI: 10.1002/GHG.2118
Abstract: Understanding wettability of clay minerals is crucial in assessing primary migration of hydrocarbon and evaluating CO 2 storage capacities and containment security. In spite of recent efforts, there is considerable uncertainty of experimental data and theoretical predictions are lacking. We, therefore, developed new correlations to predict the advancing and receding contact angles of three different clay minerals (i.e., montmorillonite, Illite and kaolinite) as a function of gas density. To do so, we first measured clay minerals advancing and receding contact angles for helium, nitrogen, argon and carbon dioxide/brine systems at various pressures (5, 10, 15 and 20 MPa) and a constant temperature of 333 K. The statistical analysis shows that the developed correlations are capable of predicting the contact angles of the three clay minerals with very high accuracy (i.e., R 0.95, for all the newly developed correlations). We thus conclude that the wettability of these clay minerals can be computed from knowledge of the gas densities, using these new empirical correlations. This work has important implications for improving wettability predictions, and thus reducing risks related to subsurface operations, such as CO 2 storage or hydrocarbon recovery. © 2021 Society of Chemical Industry and John Wiley & Sons, Ltd.
Location: Saudi Arabia
Location: No location found
No related grants have been discovered for Ahmed Al-Yaseri.