Combined Impact of Salt Precipitation and Fines Migration on CO2 Injectivity Impairment

Yusof, Muhammad Aslam Md; Mohamed, Muhammad Azfar; Akhir, Nur Asyraf Md; Ibrahim, Mohamad Arif; Mardhatillah, Mutia Kharunisa

doi:10.1016/j.ijggc.2021.103422

Cited by 14 publications

(10 citation statements)

References 35 publications

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“…Simulations demonstrated that even when dry CO 2 is introduced into a depleted gas reservoir that contains mediumsalinity brine, halite can still precipitate [101]. In addition, the combined effect of salt precipitation and fine migration can decrease the permeability three-fold compared to salt precipitation alone [102].…”

Section: Salt Precipitationmentioning

confidence: 99%

“…If the salt concentration exceeds the solubility limit under reservoir conditions, minerals precipitate [63,101]. The precipitated salt fills the porous space and clogs the pore network of the formation, modifying the flow channels [7,63,101,102]. It can reduce porosity and permeability, change capillary forces, and cause injectivity loss around the wellbore [5,7,24,27,61,63,95,[100][101][102][103] completely blocking the injection [101] and reducing oil/gas productivity [63].…”

Section: Salt Precipitationmentioning

confidence: 99%

“…The precipitated salt fills the porous space and clogs the pore network of the formation, modifying the flow channels [7,63,101,102]. It can reduce porosity and permeability, change capillary forces, and cause injectivity loss around the wellbore [5,7,24,27,61,63,95,[100][101][102][103] completely blocking the injection [101] and reducing oil/gas productivity [63]. The decrease in permeability reduces the overall porosity and affects the pore space geometry as well as the precipitate distribution within the pore space [101].…”

Section: Salt Precipitationmentioning

confidence: 99%

See 2 more Smart Citations

Carbon Capture and Storage in Depleted Oil and Gas Reservoirs: The Viewpoint of Wellbore Injectivity

Heidarabad,

Shin

2024

Energies

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Recently, there has been a growing interest in utilizing depleted gas and oil reservoirs for carbon capture and storage. This interest arises from the fact that numerous reservoirs have either been depleted or necessitate enhanced oil and gas recovery (EOR/EGR). The sequestration of CO2 in subsurface repositories emerges as a highly effective approach for achieving carbon neutrality. This process serves a dual purpose by facilitating EOR/EGR, thereby aiding in the retrieval of residual oil and gas, and concurrently ensuring the secure and permanent storage of CO2 without the risk of leakage. Injectivity is defined as the fluid’s ability to be introduced into the reservoir without causing rock fracturing. This research aimed to fill the gap in carbon capture and storage (CCS) literature by examining the limited consideration of injectivity, specifically in depleted underground reservoirs. It reviewed critical factors that impact the injectivity of CO2 and also some field case data in such reservoirs.

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Section: Salt Precipitationmentioning

confidence: 99%

Section: Salt Precipitationmentioning

confidence: 99%

Section: Salt Precipitationmentioning

confidence: 99%

See 1 more Smart Citation

Carbon Capture and Storage in Depleted Oil and Gas Reservoirs: The Viewpoint of Wellbore Injectivity

Heidarabad,

Shin

2024

Energies

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“…Several analytical and numerical models have been developed to study the physics behind salt precipitation at the core and field scales 27 , 28 , 43 – 45 . More recently, machine learning-based modelling has also been adopted to study the mechanisms of CO 2 injectivity 46 – 48 . The microstructure of natural porous media are very complex with tortuousness and often noncircular pore channels 49 – 51 .…”

Section: Introductionmentioning

confidence: 99%

Experimental and theoretical investigation of the mechanisms of drying during CO2 injection into saline reservoirs

Sokama‐Neuyam

Yusof

Owusu

et al. 2023

Sci Rep

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A viable CO2 storage resource must have sufficient storage capacity, reliable containment efficiency and adequate well injectivity. Deep saline formations stand out in terms of storage capacity and containment efficiency. However, formation brine dry-out and salt precipitation in the near well region could impair CO2 injectivity in deep saline reservoirs, thus reducing their potential for CO2 storage. Core-flood experiments and analytical modelling were used to investigate various mechanisms of external and internal salt precipitation. Particularly, the impact of the extension of the dry-out region on CO2 injectivity was investigated. It was found that, for high permeability rocks, injection of CO2 at relatively low injection rates could result in salt cake deposition at the injection inlet especially under high salinity conditions. It was also found that extension of the dry-out region does not have significant impact on CO2 injectivity. Although the magnitude of CO2 injectivity impairment increased more than two-fold when initial brine salinity was doubled, real-time changes in CO2 injectivity during the drying process was found to be independent of initial brine salinity. We have shown that the bundle-of-tubes model could provide useful insight into the process of brine vaporization and salt deposition in the dry-out region during CO2 injection. This work provides vital understanding of the effect of salt precipitation on CO2 injectivity.

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“…If the residing gas has low humidity, water may start evaporating, which can induce precipitation of the contained minerals. These precipitates could cause blockage of flow pathways and result in a negative effect on permeability and injectivity of the medium − during, e.g., underground storage of dry CO 2 or hydrogen.…”

Section: Introductionmentioning

confidence: 99%

Spontaneous Imbibition and Evaporation in Rocks at the Nanometer Scale

Wensink,

Schröer,

Dell

et al. 2023

Energy Fuels

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Understanding multiphase fluid displacement dynamics in porous media is of great importance in efficiently designing hydrogen storage projects in porous reservoirs. During gas injection and extraction, cyclic evaporation and spontaneous imbibition processes have an impact on storage efficiency. In both imbibition and evaporation, capillary films on the surface of grains play a role in the transport of water through the pore space. In this study, we use atomic force microscopy to study the formation of these films in carbonate rock during imbibition and their dynamic behavior during evaporation. The imbibition dynamics are related to pore-scale processes determined by micro-CT experiments. We find that imbibition through the mesoporous structure of the grains is slower compared to imbibition in macropores. The formation of the water film on the outer grains is also slower, indicating that a film is evolving due to water flow through intragranular mesopores rather than film flow around the grains. Evaporation experiments reveal that the film shows both local swelling and shrinkage behavior, which we relate to pore-scale processes causing disconnection of the water film. Our results show the close relationship between pore-scale processes and water film dynamics during both spontaneous imbibition and evaporation. This work forms a basis for a more quantitative study of the impact of pore structure on wetting and drying dynamics and can be extended to reactive flow processes.

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Combined Impact of Salt Precipitation and Fines Migration on CO2 Injectivity Impairment

Cited by 14 publications

References 35 publications

Carbon Capture and Storage in Depleted Oil and Gas Reservoirs: The Viewpoint of Wellbore Injectivity

Carbon Capture and Storage in Depleted Oil and Gas Reservoirs: The Viewpoint of Wellbore Injectivity

Experimental and theoretical investigation of the mechanisms of drying during CO2 injection into saline reservoirs

Spontaneous Imbibition and Evaporation in Rocks at the Nanometer Scale

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