The influence of temperature on wettability alteration during CO2 storage in saline aquifers

Abbaszadeh, Mohsen; Shariatipour, Seyed M.; Ifelebuegu, Augustine O.

doi:10.1016/j.ijggc.2020.103101

Cited by 17 publications

(7 citation statements)

References 64 publications

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“…Among the factors controlling the wettability of CO 2 –brine–rock systems, the effect of pressure and temperature is debatable. While contact angle increase toward CO 2 wetting by increasing pressure has been observed in some studies, ,,,− such a significant wettability change has not been consistently reported in other studies. ,,− Likewise, increasing the temperature is found to increase ,,,,,, or decrease − ,,, the contact angles.…”

Section: Factors Affecting the Injectivity Of Co2mentioning

confidence: 85%

“…While contact angle increase toward CO 2 wetting by increasing pressure has been observed in some studies, 67,126,127,145−152 such a significant wettability change has not been consistently reported in other studies. 134,151,153−155 Likewise, increasing the temperature is found to increase 67,69,127,149,151,152,156 or decrease [146][147][148]151,155,157 the contact angles.…”

Section: Factors Affecting the Injectivity Of Comentioning

confidence: 99%

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Well Injectivity during CO₂ Geosequestration: A Review of Hydro-Physical, Chemical, and Geomechanical Effects

et al. 2021

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Deep saline aquifers are among the most favorable geological sites for short-and long-term carbon geosequestration. Injection of CO 2 into aquifers causes various hydro-physical, chemical, and geomechanical interactions that affect the injectivity of wellbores. Despite the extensive research conducted on carbon capture and storage (CCS), there exists a lack of focus on the concept of injectivity. The present study aims to identify the gaps by reviewing the major factors contributing to CO 2 injectivity in deep saline aquifers. Moreover, the existing analytical and numerical mathematical models to estimate maximum sustainable injection pressure and pressure build-up are critically reviewed. Concerning the analytical models, the main controversies are related to the general shape of the CO 2 −brine interface that stems from neglecting or assuming CO 2 compressibility, mutual solubility of CO 2 and water, and drying-out effects. Besides, the models predicting waterflooding processes cannot accurately evaluate the injectivity of CO 2 due to the unique features of CO 2 . Furthermore, most models have concentrated on CO 2 storage capacity at the reservoir scale and not on wellbore injectivity. Thermo-poro-elastic effects influencing the in situ stresses and constraining the maximum sustainable injection pressures are also neglected in some cases. Despite the numerous numerical modeling workflows or tools, some mechanisms have not yet gained the desired attention, especially the chemical aspects of CO 2 -rich brine. Finally, while the field data demonstrate the applicability of CO 2 geosequestration in saline aquifers, regular wellbore injectivity monitoring and surveillance is deemed necessary.

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Section: Factors Affecting the Injectivity Of Co2mentioning

confidence: 85%

Section: Factors Affecting the Injectivity Of Comentioning

confidence: 99%

Well Injectivity during CO₂ Geosequestration: A Review of Hydro-Physical, Chemical, and Geomechanical Effects

et al. 2021

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“…However, with the development of the technology of underground coal gasification (UCG), Thomas Kempka used three different-rank coals in Germany as gasification raw materials to simulate the actual gasification process at 800 • C in the laboratory. The simulation results revealed a 42% increase in the physical adsorption capacity after gasification compared with that before gasification [45][46][47][48][49]. This indicates that supercritical high-pressure CO 2 storage in the UCG combustion zone is feasible in terms of physical properties.…”

Section: Introductionmentioning

confidence: 83%

Experimental Study on Relative Permeability Characteristics for CO2 in Sandstone under High Temperature and Overburden Pressure

et al. 2021

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In this study, CO2 seepage of sandstone samples from the Taiyuan-Shanxi Formation coal seam roof in Ordos Basin, China, under temperature-stress coupling was studied with the aid of the TAWD-2000 coal rock mechanics-seepage test system. Furthermore, the evolution law and influencing factors on permeability for CO2 in sandstone samples with temperature and axial pressure were systematically analyzed. The results disclose that the permeability of sandstone decreases with the increase in stress. The lower the stress is, the more sensitive the permeability is to stress variation. High stress results in a decrease in permeability, and when the sample is about to fail, the permeability surges. The permeability of sandstone falls first and then rises with the rise of temperature, which is caused by the coupling among the thermal expansion of sandstone, the desorption of CO2, and the evaporation of residual water in fractures. Finally, a quadratic function mathematical model with a fitting degree of 98.2% was constructed between the temperature-stress coupling effect and the permeability for CO2 in sandstone. The model provides necessary data support for subsequent numerical calculation and practical engineering application. The experimental study on the permeability characteristics for CO2 in sandstone under high temperature and overburden pressure is crucial for evaluating the storage potential and predicting the CO2 migration evolution in underground coal gasification coupling CO2 storage projects.

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“…5,6 Yet, the risk of uncontrollable CO 2 leakage into the atmosphere hinders its large-scale implementation; 4,7 according to the Intergovernmental Panel on Climate Change, CO 2 leakage would most likely occur along the wellbores bringing crucial risk of CO 2 migration to the surface. 6,8 Even so, the geological storage of CO 2 still shows great potential specially in terms of storage capacity. Of particular interest is to encapsulate CO 2 in a solid phase through forming gas hydrates with local fluids.…”

Section: Introductionmentioning

confidence: 99%

“…Reducing carbon emissions has been an urgent issue in many industrial powers. Consequently, the idea of CO 2 capture and storage is proposed for an efficient CO 2 control. , Specially, unique geological settings like submarine aquifers beneath the caprock layers are expected to be a promising region for CO 2 storage. , Yet, the risk of uncontrollable CO 2 leakage into the atmosphere hinders its large-scale implementation; , according to the Intergovernmental Panel on Climate Change, CO 2 leakage would most likely occur along the wellbores bringing crucial risk of CO 2 migration to the surface. , Even so, the geological storage of CO 2 still shows great potential specially in terms of storage capacity. Of particular interest is to encapsulate CO 2 in a solid phase through forming gas hydrates with local fluids. , Other than a huge volume compressibility of the gas and thus a high storage density determined by the unique molecular structure of gas hydrate, the existence of CO 2 in the form of a solid phase would also enable a broader applicability in terms of site selection where a caprock necessary for a dissolution-based storage technique is no longer requisite .…”

Section: Introductionmentioning

confidence: 99%

Behaviors of CO₂ Hydrate Formation in the Presence of Acid-Dissolvable Organic Matters

Liu

Zhang

Yang

et al. 2021

Environ. Sci. Technol.

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Carbon storage in the form of solid hydrate under seafloor has been considered to be promising for greenhouse gas control. Yet, open issues still remain on the role of the organic matters abundant in marine environments in the kinetics of hydrate formation; of particular interest is the involvement of the acid-dissolvable organic matters accompanying the acidification upon CO2 injection. In this work, the CO2 hydrate formation in the presence of the organic matters was in-situ monitored through the low-field nuclear magnetic resonance technique. It was found that the organic matters could kinetically promote the formation of CO2 hydrate; this effect was further enhanced by the sulfur-containing acid-dissolvable organic matters. Water in the large pores was preferentially consumed; the following water conversion facilitated by the organic matters would result in a fragmentation of the large pores into separated small pores isolated by the hydrate clusters. Consequently, a further enhancement of the gas–water contact is suggested as the existence of substantial hydrate patches could act as a mass transfer barrier. Our findings expand our understandings on the kinetics of CO2 hydrate formation in the presence of the organic matters and indicate the stability zone of gas hydrate a kinetically favorable geological setting for CO2 sequestration.

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The influence of temperature on wettability alteration during CO2 storage in saline aquifers

Cited by 17 publications

References 64 publications

Well Injectivity during CO₂ Geosequestration: A Review of Hydro-Physical, Chemical, and Geomechanical Effects

Well Injectivity during CO₂ Geosequestration: A Review of Hydro-Physical, Chemical, and Geomechanical Effects

Experimental Study on Relative Permeability Characteristics for CO2 in Sandstone under High Temperature and Overburden Pressure

Behaviors of CO₂ Hydrate Formation in the Presence of Acid-Dissolvable Organic Matters

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The influence of temperature on wettability alteration during CO2 storage in saline aquifers

Cited by 17 publications

References 64 publications

Well Injectivity during CO2 Geosequestration: A Review of Hydro-Physical, Chemical, and Geomechanical Effects

Well Injectivity during CO2 Geosequestration: A Review of Hydro-Physical, Chemical, and Geomechanical Effects

Experimental Study on Relative Permeability Characteristics for CO2 in Sandstone under High Temperature and Overburden Pressure

Behaviors of CO2 Hydrate Formation in the Presence of Acid-Dissolvable Organic Matters

Contact Info

Product

Resources

About

Well Injectivity during CO₂ Geosequestration: A Review of Hydro-Physical, Chemical, and Geomechanical Effects

Well Injectivity during CO₂ Geosequestration: A Review of Hydro-Physical, Chemical, and Geomechanical Effects

Behaviors of CO₂ Hydrate Formation in the Presence of Acid-Dissolvable Organic Matters