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Assessment of chemo-mechanical impacts of CO 2 sequestration on the caprock formation in Farnsworth oil field, Texas.
- Source :
-
Scientific reports [Sci Rep] 2022 Jul 29; Vol. 12 (1), pp. 13023. Date of Electronic Publication: 2022 Jul 29. - Publication Year :
- 2022
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Abstract
- This study evaluates the chemo-mechanical influence of injected CO <subscript>2</subscript> on the Morrow B sandstone reservoir and the upper Morrow shale caprock utilizing data from the inverted 5-spot pattern centered on Well 13-10A within the Farnsworth unit (FWU). This study also seeks to evaluate the integrity of the caprock and the long-term CO <subscript>2</subscript> storage capability of the FWU. The inverted 5-spot pattern was extracted from the field-scale model and tuned with the available field observed data before the modeling work. Two coupled numerical simulation models were utilized to continue the study. First, a coupled hydro-geochemical model was constructed to simulate the dissolution and precipitation of formation minerals by modeling three intra-aqueous and six mineral reactions. In addition, a coupled hydro-geomechanical model was constructed and employed to study the effects of stress changes on the caprock's porosity, permeability, and ground displacement. The Mohr-Coulomb circle and failure envelope were used to determine caprock failure. In this work, the CO <subscript>2</subscript> -WAG injection is followed by the historical field-observed strategy. During the forecasting period, a Water Alternating Gas (WAG) injection ratio of 1:3 was utilized with a baseline bottom-hole pressure constraint of 5500 psi for 20 years. A post-injection period of 1000 years was simulated to monitor the CO <subscript>2</subscript> plume and its effects on the CO <subscript>2</subscript> storage reservoir and caprock integrity. The simulation results indicated that the impacts of the geochemical reactions on the porosity of the caprock were insignificant as it experienced a decrease of about 0.0003% at the end of the 1000-year post-injection monitoring. On the other hand, the maximum stress-induced porosity change was about a 1.4% increase, resulting in about 4% in permeability change. It was estimated that about 3.3% of the sequestered CO <subscript>2</subscript> in the formation interacted with the caprock. Despite these petrophysical property alterations and CO <subscript>2</subscript> interactions in the caprock, the caprock still maintained its elastic properties and was determined to be far from its failure.<br /> (© 2022. This is a U.S. Government work and not under copyright protection in the US; foreign copyright protection may apply.)
- Subjects :
- Minerals
Porosity
Texas
Carbon Dioxide chemistry
Oil and Gas Fields
Subjects
Details
- Language :
- English
- ISSN :
- 2045-2322
- Volume :
- 12
- Issue :
- 1
- Database :
- MEDLINE
- Journal :
- Scientific reports
- Publication Type :
- Academic Journal
- Accession number :
- 35906463
- Full Text :
- https://doi.org/10.1038/s41598-022-16990-x