Lessons Learned from CO2 Injection, Monitoring, and Modeling Across a Diverse Portfolio of Depleted Closed Carbonate Reef Oil Fields – The Midwest Regional Carbon Sequestration Partnership Experience

Gupta, Neeraj; Kelley, Mark; Place, Matt; Cumming, Lydia; Mawalkar, Sanjay; Mishra, Srikanta; Haagsma, Autumn; Mannes, Robert; Pardini, Rick

doi:10.1016/j.egypro.2017.03.1694

Cited by 12 publications

(5 citation statements)

References 7 publications

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“…Researchers and industry stakeholders have been conducting extensive studies and research efforts to better understand the interaction between regional pressure changes and CO 2 plume migration [8,118]. Several case studies have provided valuable insights into the real-world challenges and solutions related to this issue.…”

Section: Co 2 Plume Migrationmentioning

confidence: 99%

Impact of Regional Pressure Dissipation on Carbon Capture and Storage Projects: A Comprehensive Review

Hawez,

Asim

2024

Energies

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Carbon capture and storage (CCS) is a critical technology for mitigating greenhouse gas emissions and combating climate change. CCS involves capturing CO2 emissions from industrial processes and power plants and injecting them deep underground for long-term storage. The success of CCS projects is influenced by various factors, including the regional pressure dissipation effects in subsurface geological formations. The safe and efficient operation of CCS projects depends on maintaining the pressure in the storage formation. Regional pressure dissipation, often resulting from the permeability and geomechanical properties of the storage site, can have significant effects on project integrity. This paper provides a state-of-art of the impact of regional pressure dissipation on CCS projects, highlights its effects, and discusses ongoing investigations in this area based on different case studies. The results corroborate the idea that the Sleipner project has considerable lateral hydraulic connectivity, which is evidenced by pressure increase ranging from <0.1 MPa in case of an uncompartmentalized reservoir to >1 MPa in case of substantial flow barriers. After five years of injection, pore pressures in the water leg of a gas reservoir have increased from 18 MPa to 30 MPa at Salah project, resulting in a 2 cm surface uplift. Furthermore, artificial CO2 injection was simulated numerically for 30 years timespan in the depleted oil reservoir of Jurong, located near the Huangqiao CO2-oil reservoir. The maximum amount of CO2 injected into a single well could reach 5.43 × 106 tons, potentially increasing the formation pressure by up to 9.5 MPa. In conclusion, regional pressure dissipation is a critical factor in the implementation of CCS projects. Its impact can affect project safety, efficiency, and environmental sustainability. Ongoing research and investigations are essential to improve our understanding of this phenomenon and develop strategies to mitigate its effects, ultimately advancing the success of CCS as a climate change mitigation solution.

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Section: Co 2 Plume Migrationmentioning

confidence: 99%

Impact of Regional Pressure Dissipation on Carbon Capture and Storage Projects: A Comprehensive Review

Hawez,

Asim

2024

Energies

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“…The reefs could be potential candidate sites for CO 2 storage since several of them (∼ 800 reefs in the Northern Pinnacle Reef Trend) already exist in the Michigan basin 24–26 . CO 2 was injected into the selected reefs in different periods to support enhanced oil recovery and CO 2 storage 27–30 . The Brown Niagaran dolomite formation is considered the main reservoir of the reefs.…”

Section: Experimental Measurement Of Ultrasonic Wave Velocities Under...mentioning

confidence: 99%

Quantifying the impact of effective stress on changes in elastic wave velocities due to CO₂ injection into a depleted carbonate reef

2021

Self Cite

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The interpretation of time‐lapse seismic monitoring of CO2 sequestration has typically focused on mapping the saturation and pressure changes. However, elastic wave velocity and associated seismic attribute variation also depend on the poroelastic response to CO2 injection. In this study, we investigated the impact of effective stress changes on elastic wave velocity responses during CO2 storage within a carbonate reef of the Michigan basin. The geomechanical multiphase flow modeling combined with the experimental measurements were used to investigate the impact of effective stress on changes in velocities. We measured the ultrasonic compressional (Vp) and shear (Vs) wave velocities in cores acquired from the carbonate formations under different stress‐pressure scenarios. Experimental scenarios were applied by changing the effective stress and pore pressure conditions simulating injection into the depleted reservoir. Experimental results show that incorporating stress changes of injection avoids overestimation of changes in velocities due to considering only pore pressure effects. Coupled multiphase flow – geomechanical simulations were performed to assess stress and saturation change during CO2 injection. We discussed expected changes in elastic wave velocities using combined simulation results with experimental ones. The simulation results show that both effective stress and saturation changes contribute to changes in velocities in the main reservoir. Effective stress is the dominant parameter that contributes to changes in velocities in the upper formations. Results of this work show that quantifying the poroelastic effect of stress on elastic wave velocities changes can lead to a better interpretation of changes in seismic attributes during CO2 injection. © 2021 Society of Chemical Industry and John Wiley & Sons, Ltd.

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“…The reef system can provide commercial-scale CO 2 storage owing to the sizable number of such reefs in the Michigan basin (approximately 800 of them in the northern Niagara reef trend and approximately 400 in the southern Niagara reef trend). [57][58][59] The mechanical properties of the reservoir were defined to the extent possible from laboratory core data and from results of analyses of sonic log data for the reference well and other close by wells in the Northern Pinnacle Reef Trend of the Michigan basin. 60 The Young's modulus of the reservoir formation (Brown Niagaran) ranged from 41.3 to 96.5 GPa.…”

Section: Base Case Hydromechanical Responsementioning

confidence: 99%

Statistical based hydromechanical models to estimate poroelastic effects of CO₂ injection into a closed reservoir

Raziperchikolaee

Mishra

2020

Greenhouse Gases

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In this study, a statistical‐based methodology is used to evaluate the poroelastic effects of injection during CO2 geologic sequestration in a closed reservoir. We constructed a series of hydromechanical models to evaluate the poroelastic effect of injection by quantifying total stress changes inside the reservoir, reservoir displacement, and surface uplift. The models are representative of closed carbonate reef reservoirs of the Michigan basin. A combination of experimental design for seven independent parameters (depth, caprock and reservoir Young's modulus, caprock and reservoir Poisson's ratio, pressure, and Biot's coefficient) and response surface modeling was used to develop statistical‐based reduced‐order models. We performed 147 numerical simulations to develop simplified models. The poroelastic model responses were captured using a standard quadratic model with full interaction terms, as well as a reduced model with only statistically significant coefficients. The interpretation of reduced‐order models, using R2 loss method, shows that while surface uplift depends mainly on the depth of the reservoir, stress increase depends mainly on Biot's coefficient. The developed statistical‐based models provide a quick tool to evaluate the poroelastic effect of injection into the closed carbonate reservoirs of the Michigan basin. Reduced‐order models were then combined with a Monte Carlo simulation to perform poroelastic uncertainty analyses and achieve a better understanding of the poroelastic performance of CO2 storage in the closed carbonate system of the Michigan basin. © 2020 Society of Chemical Industry and John Wiley & Sons, Ltd.

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Lessons Learned from CO2 Injection, Monitoring, and Modeling Across a Diverse Portfolio of Depleted Closed Carbonate Reef Oil Fields – The Midwest Regional Carbon Sequestration Partnership Experience

Cited by 12 publications

References 7 publications

Impact of Regional Pressure Dissipation on Carbon Capture and Storage Projects: A Comprehensive Review

Impact of Regional Pressure Dissipation on Carbon Capture and Storage Projects: A Comprehensive Review

Quantifying the impact of effective stress on changes in elastic wave velocities due to CO₂ injection into a depleted carbonate reef

Statistical based hydromechanical models to estimate poroelastic effects of CO₂ injection into a closed reservoir

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Lessons Learned from CO2 Injection, Monitoring, and Modeling Across a Diverse Portfolio of Depleted Closed Carbonate Reef Oil Fields – The Midwest Regional Carbon Sequestration Partnership Experience

Cited by 12 publications

References 7 publications

Impact of Regional Pressure Dissipation on Carbon Capture and Storage Projects: A Comprehensive Review

Impact of Regional Pressure Dissipation on Carbon Capture and Storage Projects: A Comprehensive Review

Quantifying the impact of effective stress on changes in elastic wave velocities due to CO2 injection into a depleted carbonate reef

Statistical based hydromechanical models to estimate poroelastic effects of CO2 injection into a closed reservoir

Contact Info

Product

Resources

About

Quantifying the impact of effective stress on changes in elastic wave velocities due to CO₂ injection into a depleted carbonate reef

Statistical based hydromechanical models to estimate poroelastic effects of CO₂ injection into a closed reservoir