Hydrate Plugging and Flow Remediation during CO<sub>2</sub> Injection in Sediments
Successful geological sequestration of carbon depends strongly on reservoir seal integrity and storage capacity, including CO<sub>2</sub> injection efficiency. Formation of solid hydrates in the near-wellbore area during CO<sub>2</sub> injection can cause permeability impairm...
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| Language: | English |
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MDPI AG
2020-09-01
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| Series: | Energies |
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| Online Access: | https://www.mdpi.com/1996-1073/13/17/4511 |
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| author | Jarand Gauteplass Stian Almenningen Tanja Barth Geir Ersland |
| author_facet | Jarand Gauteplass Stian Almenningen Tanja Barth Geir Ersland |
| author_sort | Jarand Gauteplass |
| collection | DOAJ |
| description | Successful geological sequestration of carbon depends strongly on reservoir seal integrity and storage capacity, including CO<sub>2</sub> injection efficiency. Formation of solid hydrates in the near-wellbore area during CO<sub>2</sub> injection can cause permeability impairment and, eventually, injectivity loss. In this study, flow remediation in hydrate-plugged sandstone was assessed as function of hydrate morphology and saturation. CO<sub>2</sub> and CH<sub>4</sub> hydrates formed consistently at elevated pressures and low temperatures, reflecting gas-invaded zones containing residual brine near the injection well. Flow remediation by methanol injection benefited from miscibility with water; the methanol solution contacted and dissociated CO<sub>2</sub> hydrates via liquid water channels. Injection of N<sub>2</sub> gas did not result in flow remediation of non-porous CO<sub>2</sub> and CH<sub>4</sub> hydrates, likely due to insufficient gas permeability. In contrast, N<sub>2</sub> as a thermodynamic inhibitor dissociated porous CH<sub>4</sub> hydrates at lower hydrate saturations (<0.48 frac.). Core-scale thermal stimulation proved to be the most efficient remediation method for near-zero permeability conditions. However, once thermal stimulation ended and pure CO<sub>2</sub> injection recommenced at hydrate-forming conditions, secondary hydrate formation occurred aggressively due to the memory effect. Field-specific remediation methods must be included in the well design to avoid key operational challenges during carbon injection and storage. |
| first_indexed | 2024-03-10T16:39:36Z |
| format | Article |
| id | doaj.art-3dbe39e9b952408896ac77c700fc7519 |
| institution | Directory Open Access Journal |
| issn | 1996-1073 |
| language | English |
| last_indexed | 2024-03-10T16:39:36Z |
| publishDate | 2020-09-01 |
| publisher | MDPI AG |
| record_format | Article |
| series | Energies |
| spelling | doaj.art-3dbe39e9b952408896ac77c700fc75192023-11-20T12:06:29ZengMDPI AGEnergies1996-10732020-09-011317451110.3390/en13174511Hydrate Plugging and Flow Remediation during CO<sub>2</sub> Injection in SedimentsJarand Gauteplass0Stian Almenningen1Tanja Barth2Geir Ersland3Department of Physics and Technology, University of Bergen, 5007 Bergen, NorwayDepartment of Physics and Technology, University of Bergen, 5007 Bergen, NorwayDepartment of Chemistry, University of Bergen, 5007 Bergen, NorwayDepartment of Physics and Technology, University of Bergen, 5007 Bergen, NorwaySuccessful geological sequestration of carbon depends strongly on reservoir seal integrity and storage capacity, including CO<sub>2</sub> injection efficiency. Formation of solid hydrates in the near-wellbore area during CO<sub>2</sub> injection can cause permeability impairment and, eventually, injectivity loss. In this study, flow remediation in hydrate-plugged sandstone was assessed as function of hydrate morphology and saturation. CO<sub>2</sub> and CH<sub>4</sub> hydrates formed consistently at elevated pressures and low temperatures, reflecting gas-invaded zones containing residual brine near the injection well. Flow remediation by methanol injection benefited from miscibility with water; the methanol solution contacted and dissociated CO<sub>2</sub> hydrates via liquid water channels. Injection of N<sub>2</sub> gas did not result in flow remediation of non-porous CO<sub>2</sub> and CH<sub>4</sub> hydrates, likely due to insufficient gas permeability. In contrast, N<sub>2</sub> as a thermodynamic inhibitor dissociated porous CH<sub>4</sub> hydrates at lower hydrate saturations (<0.48 frac.). Core-scale thermal stimulation proved to be the most efficient remediation method for near-zero permeability conditions. However, once thermal stimulation ended and pure CO<sub>2</sub> injection recommenced at hydrate-forming conditions, secondary hydrate formation occurred aggressively due to the memory effect. Field-specific remediation methods must be included in the well design to avoid key operational challenges during carbon injection and storage.https://www.mdpi.com/1996-1073/13/17/4511CCScarbon storageinjectivityhydrate formationflow remediationCO<sub>2</sub> |
| spellingShingle | Jarand Gauteplass Stian Almenningen Tanja Barth Geir Ersland Hydrate Plugging and Flow Remediation during CO<sub>2</sub> Injection in Sediments Energies CCS carbon storage injectivity hydrate formation flow remediation CO<sub>2</sub> |
| title | Hydrate Plugging and Flow Remediation during CO<sub>2</sub> Injection in Sediments |
| title_full | Hydrate Plugging and Flow Remediation during CO<sub>2</sub> Injection in Sediments |
| title_fullStr | Hydrate Plugging and Flow Remediation during CO<sub>2</sub> Injection in Sediments |
| title_full_unstemmed | Hydrate Plugging and Flow Remediation during CO<sub>2</sub> Injection in Sediments |
| title_short | Hydrate Plugging and Flow Remediation during CO<sub>2</sub> Injection in Sediments |
| title_sort | hydrate plugging and flow remediation during co sub 2 sub injection in sediments |
| topic | CCS carbon storage injectivity hydrate formation flow remediation CO<sub>2</sub> |
| url | https://www.mdpi.com/1996-1073/13/17/4511 |
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