Effect of humic acid on CO2-wettability in sandstone formation

Ali, Mujahid; Awan, Faisal Ur Rahman; Ali, Muhammad; Al-Yaseri, Ahmed; Arif, Muhammad; Sánchez‐Román, Mónica; Keshavarz, Alireza; Iglauer, Stefan

doi:10.1016/j.jcis.2020.12.058

Cited by 82 publications

(30 citation statements)

References 91 publications

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“…Our previous study on calcite/H 2 /water showed a smooth variation of the contact angle with surface roughness as it is widely reported in the wettability studies that surface roughness less than 1 μm does not have any significant impact on the contact angles. , H 2 gas (99.9 mol %) and 1.05 M brine (0.864 mol fraction NaCl + 0.136 mol fraction KCl) prepared by mixing the salts (purities of NaCl and KCl ≥0.99 mol fraction) with deionized water (electrical conductivity = 0.02 mS cm –1 ) were used for the experiments. To clean contaminants from the mineral surface, we first washed the samples with deionized water . Then, ultra-pure nitrogen (99.9 mol %) was used to wipe off the water film from the surfaces, which were then dried in an oven at 338 K for 60 min .…”

Section: Methodsmentioning

confidence: 99%

Capillary Sealing Efficiency Analysis of Caprocks: Implication for Hydrogen Geological Storage

et al. 2022

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In hydrogen geological storage, capillary sealing efficiency analysis of caprocks is very important for containment security. In this work, the H2 wettabilities of three shales and one evaporite under various pressures (0.1, 5, 10, 15, and 20 MPa), temperatures (298 and 353 K), and organic acid concentrations (10–9 to 10–2 mol/L) were measured using the tilted plate method, and their effects on the capillary sealing efficiency of the caprocks were analyzed. Furthermore, two oil shales were tested to see the effect of their total organic content (TOC) on the wettability at two different pressure (5 and 15 MPa) and temperature (323 and 353 K) values since the TOC dramatically varies in shales and can significantly influence the wetting characteristics and, thus, the sealing efficiency. The results of this study indicate that the H2 wettability of the caprocks increased with pressure, organic acid concentration, and TOC but decreased with temperature. However, the sealing efficiency and H2 column height of the caprocks decreased with all the varying parameters but increased with temperature for oil shales. Furthermore, small pore sizes (i.e., r = 5 nm as a typical value for this study) and evaporites (e.g., gypsum) have the most efficient conditions for sealing for increased storage capacity. Overall, this work provides a deep understanding of the sealing efficiency of caprocks, which will aid in the successful implementation of hydrogen geo-storage and its associated structural trapping capacities.

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Section: Methodsmentioning

confidence: 99%

Capillary Sealing Efficiency Analysis of Caprocks: Implication for Hydrogen Geological Storage

et al. 2022

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“…In the WW rock, the molecules in the THF–brine solution bind to the surface of the pores unlike OW rock, which repels THF–brine from its pore walls due to its hydrophobic nature. Sandstone rocks (which predominantly consist of quartz) are WW naturally; however, organic molecules that are naturally present in the subsurface alter sandstone more hydrophobic (even in an aquifer ,,,, ). Consequently, S h decreased as hydrate dissociated with increasing temperature.…”

Section: Resultsmentioning

confidence: 99%

“…The values of “ m ” may range from as low as 0.8 to 1.5 for sphere packs , and up to 5.3 in marine sediments, “ a ” ranges between 0.8 and 5.8, , and “ n ” values range from 0.5 to 4, but usually from 2.5 ± 0.5. , However, to the best of our knowledge, the influence of rock wettability on rock hydrate electrical properties has not yet been systematically studied. This is despite wettability being a prime factor in multiphase fluid flow, fluid distribution, and recovery plans. − It is also clear that rock wettability can vary substantially, even in aquifer settings; this is mainly due to the organic content of the rock, which affects wettability even at very minute concentrations. − …”

Section: Introductionmentioning

confidence: 99%

Effect of Rock Wettability on the Electric Resistivity of Hydrate Formations: An Experimental Investigation

et al. 2021

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Gas hydrates are large energy resources with estimated global reserves of approximately 500–10 000 Gt of carbon, which can be extracted from underground reservoirs. In addition, such reservoirs can potentially catastrophically release greenhouse gases (such as methane or carbon dioxide). Classically, rock wettability is one of the key factors in predicting fluid flow behavior, fluid distribution, reserves, and productivities. However, the effect of wettability on the electric resistivity of hydrate formations is poorly understood. Thus, to evaluate the influence of rock wettability on the electrical resistivity (note that resistivity logging is a key well logging tool) of hydrate-bearing sandstone, nuclear magnetic resonance experiments were conducted. Clearly, the effective porosity and liquid saturation increased with increasing temperature, due to hydrate dissociation. Furthermore, the resistivity index and rock resistivity (R t) increased with increasing hydrate saturation, and the formation factor demonstrated a positive correlation with hydrate saturation, though the formation factor for oil-wet (OW) sandstone was higher than that for water-wet (WW) sandstone. This work will thus significantly improve the fundamental understanding of the petrophysical properties of gas hydrate reservoirs so that energy production can be optimized, geohazards can be avoided, and the hydrate gun hypothesis can be better assessed.

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“…This trend is consistent with that observed in previous research, where the aging of rock surfaces in n-decane/stearic acid solution resulted in the attainment of intermediate water-wet and CO 2 -wet conditions. 20,33,34,77 By contrast, when the quartz and Fontainebleau quartz surfaces are aged in acetone/stearic acid solution and methanol/stearic acid solution, the substrate surfaces are only altered into weakly water-wet conditions at the highest experimental temperature and pressure used herein (323 K and 20 MPa). Under those conditions, the presence of stearic acid/ acetone shifts the advancing and receding contact angles of the non-porous quartz from θ a = 67°and θ r = 61°to θ a = 80°and θ r = 76°(Figure 4d).…”

Section: Effects Of Thementioning

confidence: 93%

Effects of Various Solvents on Adsorption of Organics for Porous and Nonporous Quartz/CO₂/Brine Systems: Implications for CO₂ Geo-Storage

et al. 2022

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The underground geo-storage of carbon dioxide (CO 2 ) is an essential component of the carbon capture and sequestration value chain. The success of CO 2 containment depends on the wetting state of the rock, which controls the mechanism of fluid flow and distribution. The presence of organic acids in the storage formation introduces a considerable effect on the wettability of the rock/CO 2 /brine system under various temperature and pressure conditions. Despite the previous studies on this topic, the impact of the substrate pores, the rock surface roughness, and the solvents used to prepare the organic acid solution under various temperatures and pressures has not yet been elucidated. In the present study, the contact angles of non-porous quartz and porous Fontainebleau quartz are measured in CO 2 /brine systems at various pressures of 0.1−20 MPa and temperatures of 298 and 323 K. In addition, various solvents are used to prepare the stearic acid solution in order to assess their influence on the adsorption of organics for porous and non-porous quartz/CO 2 /brine systems. The results clearly indicate that n-decane is the most effective solvent for solubilizing the stearic acid to attain full wettability of the substrate by CO 2 due to its polar compatibility with the stearic acid. Generally, the porous aged Fontainebleau quartz exhibits higher contact angles than the aged non-porous quartz at higher pressures, and the unaged Fontainebleau surfaces demonstrate water wettability, with a wide range of advancing and receding contact angles of less than 90°. However, when the pressure is increased to 15 and 20 MPa in the CO 2 /brine system, the contact angles of the Fontainebleau quartz are higher than those of pure quartz. These results suggest that the surface roughness of the rock merely amplifies the inherent surface chemistry and original wettability of the rock if surface conditions are hydrophobic.

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Effect of humic acid on CO2-wettability in sandstone formation

Cited by 82 publications

References 91 publications

Capillary Sealing Efficiency Analysis of Caprocks: Implication for Hydrogen Geological Storage

Capillary Sealing Efficiency Analysis of Caprocks: Implication for Hydrogen Geological Storage

Effect of Rock Wettability on the Electric Resistivity of Hydrate Formations: An Experimental Investigation

Effects of Various Solvents on Adsorption of Organics for Porous and Nonporous Quartz/CO₂/Brine Systems: Implications for CO₂ Geo-Storage

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Effect of humic acid on CO2-wettability in sandstone formation

Cited by 82 publications

References 91 publications

Capillary Sealing Efficiency Analysis of Caprocks: Implication for Hydrogen Geological Storage

Capillary Sealing Efficiency Analysis of Caprocks: Implication for Hydrogen Geological Storage

Effect of Rock Wettability on the Electric Resistivity of Hydrate Formations: An Experimental Investigation

Effects of Various Solvents on Adsorption of Organics for Porous and Nonporous Quartz/CO2/Brine Systems: Implications for CO2 Geo-Storage

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Effects of Various Solvents on Adsorption of Organics for Porous and Nonporous Quartz/CO₂/Brine Systems: Implications for CO₂ Geo-Storage