In 2003 the US Department of Energy DOE set up seven regional partnerships across the North American Region to study the technologies and strategies of CO 2 sequestration and CO 2 enhanced oil recovery EOR ID: 909575
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BackgroundCarbon Capture, Utilization, and Storage (CCUS) is one of the technologies being relied upon to avert global warming. In 2003, the U.S. Department of Energy (DOE) set up seven regional partnerships across the North American Region to study the technologies and strategies of CO2 sequestration and CO2 enhanced oil recovery (EOR). The Southwest Regional Partnership (SWP), which works with the operator of the Farnworth Field Unit (FWU) located in Ochiltree County, Texas, has conducted several studies in the FWU.The SWP studies include numerical simulations to evaluate the effects of coupling hydrodynamical and geochemical models on CO2 storage and the petrophysical properties of the Morrow B sandstone. Other studies have used coupled hydrodynamical and geomechanics simulation models to evaluate the integrity of the caprocks of the FWU.
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Methodology
Future Directions
This work serves as a benchmark for future CO2 sequestration and CO2-EOR studies.Future studies will investigate the effects of coupled hydrodynamical, geochemical and geomechanical models on CO2 sequestration in the inverted five-spot pattern with a flux boundary and a full-field application.
Evaluation Of Chemo-mechanical Impacts Of CO2 Injection To Depleted Oil Reservoirs.
Benjamin Adu-Gyamfi, William Ampomah, Qian Sun, Robert Will, Jiawei Tu
Petroleum Recovery Research Center, New Mexico Institute of Mining and Technology
ObjectivesTo present a rigorous approach in evaluating the impacts of CO2 injection in CO2 sequestration operations in a depleted Morrow B sandstone of the FWU by including mechanical responses to the CO2 sequestration aspect of CCUS. To evaluate the effects of chemo-mechanical alteration of formation properties on CO2 storage mechanisms in the Morrow B sandstone reservoir using coupled numerical hydrodynamical, geochemical, and geomechanical simulation models.To evaluate the long-term CO2 storage capacity of the FWU.
Adopt simulation model
Set up inverted five-spot pattern
Conduct history matching
Set up baseline model (hydrodynamical model)Modeled 3 trapping mechanisms
Run 1000-year prediction after wells shut-in
Set up coupled hydrodynamical and geochemical (HGC) model
Set up coupled hydrodynamical and geomechanical (HGM) model
Set up coupled hydrodynamical, geochemical and geomechanical (HGCM) models
Run 1000-year prediction after wells shut-in
Run 1000-year prediction after wells shut-in
Run 500-year prediction after wells shut-in
Acknowledgements
Funding for this project is provided by the U.S. Department of Energy's (DOE) National Energy Technology Laboratory (NETL) through the Southwest Regional Partnership on Carbon Sequestration (SWP) under Award No. DE-FC26-05NT42591.
Slide2[1] IPCC (2007): Climate Change 2007: The Physical Science Basis, contribution of Working 591 Group I to the Fourth Assessment Report of the IPCC, in: Solomon, S., Qin, D., Manning, 592 M., Marquis, M., Averyt, K., Tignor, M.M.B., LeRoy Miller, J., H., Chen, Z. (Eds.). 593 Cambridge University Press, Cambridge and New York, 594 pp.[2] Mac Dowell, N., Fennell, P., Shah, N. et al. The role of CO2 capture and utilization in mitigating climate change. Nature Clim Change 7, 243–249 (2017). https://doi.org/10.1038/nclimate3231[3] Ampomah, W., Balch, R., Cather, M., Rose-Coss, D., Dai, Z., Heath, J., Mozley, P. (2016). Evaluation of CO2 Storage Mechanisms in CO
2 Enhanced Oil Recovery Sites: Application to Morrow Sandstone Reservoir. Energy and Fuels, 30(10), 8545–8555. https://doi.org/10.1021/acs.energyfuels.6b01888
[4] Kutsienyo, E. J., Ampomah, W., Sun, Q., Balch, R. S., You, J., Aggrey, W. N., & Cather, M. (2019, June 3). Evaluation of CO2-EOR Performance and Storage Mechanisms in an Active Partially Depleted Oil Reservoir. Society of Petroleum Engineers. doi:10.2118/195534-MS
[5] Sun, Q., Ampomah, W., Kutsienyo, E. J., Appold, M., Adu-Gyamfi, B., Dai, Z., & Soltanian, M. R. (2020). Assessment of CO
2 trapping mechanisms in partially depleted oil-bearing sands. Fuel, 278, 118356. https://doi.org/10.1016/j.fuel.2020.118356
Results
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Conclusions
In the four models, all of which used fixed boundary conditions, most CO
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was stored as free gas in the reservoir, followed by residual gas, dissolution in oil, and aqueous phases.The dissolution of calcite was faster than precipitation and therefore, resulted in no net formation of carbonate mineral.The changes in rock properties due to the effects of variations in stress that are reflected in coupled hydro-geomechanical models are observed to have more influence on the porosity and permeability properties than the chemical reactions.Again, the changes in rock properties in coupled hydro-geomechanical models are observed to have more influence on the CO2 injectivity.In CO2 sequestration and/or EOR storage capacity simulation studies, it is recommended to model coupled hydro-geomechanics to ensure a more realistic responses to the CO2 injection. Evaluation Of Chemo-mechanical Impacts Of CO2 Injection To Depleted Oil Reservoirs.
Benjamin Adu-Gyamfi, William Ampomah, Qian Sun, Robert Will, Jiawei Tu
Petroleum Recovery Research Center, New Mexico Institute of Mining and Technology
References
Mineral precipitation
Mineral dissolution
Permeability change in
geomechanical model
Porosity change in geomechanical model
Layer 1
Layer 2
Layer 3
Layer 4
Porosity change in geochemical model