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All Journal Journal of Sustainable Energy Development Scientific Contributions Oil and Gas
Arik
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Chemical Engineering, Chemistry & Bioengineering Energy Engineering

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Simulasi Kinerja Enhanced Oil Recovery (EOR) dengan Polymer dan Solvent CO2 pada Sumur Injeksi di Lapangan Norne Segmen C Arik; Eriska Eklezia Dwi Saputri
JSED Vol. 3 No. 2 (2025): Journal of Sustainable Energy Development
Publisher : Universitas Jember

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.19184/jsed.v3i2.60003

Abstract

The threat of an energy crisis driven by declining production from conventional wells and depleting global oil reserves can be mitigated through Enhanced Oil Recovery (EOR), which has the potential to increase production by 30-60%. This study evaluates the potential application of EOR using polymer and CO2 solvent injections in Segment C of the Norne Field, Norway. The primary objective of this study is to determine the recovery factor, observe the vertical and areal dynamics of oil saturation, and compare the effectiveness of both methods. Continuous injection simulations were applied to wells C-1H, C-2H, C-3H, and C-4H. The results indicate that the oil recovery factor from polymer injection in well C-2H reached 49%, outperforming both the CO2 solvent injection (46.45%) and the basecase scenario (46%). Meanwhile, the gas recovery factors for the basecase, polymer, and CO2 solvent were recorded at 70.50%, 61%, and 71%, respectively. Furthermore, fluid movement evaluation shows that polymer injection provides a more uniform areal sweep efficiency both macroscopically and microscopically, unlike the CO2 solvent, which is prone to segregation within the reservoir. In conclusion, the continuous polymer injection method demonstrates superior performance compared to continuous CO2 solvent injection in the Norne Field Segment C.
Optimizing CO2 Storage Strategies for Enhanced MineralTrapping and Plume Containment in The Aquifer Zoneof an Indonesian Gas Reservoir Iskandar, Utomo Pratama; Arik; Panuju; Grandis, Garindia; Ilham, Nanda
Scientific Contributions Oil and Gas Vol 49 No 2 (2026)
Publisher : Testing Center for Oil and Gas LEMIGAS

Show Abstract | Download Original | Original Source | Check in Google Scholar | DOI: 10.29017/scog.v49i2.2067

Abstract

This study evaluates optimized CO₂ storage strategies in the aquifer zone of the SK gas field in Indonesia to improve plume containment and explore the potential for enhanced mineral trapping. A coupled compositional-flow and reactive-transport simulation workflow was applied using an upscaled reservoir model under a common safe operating pressure envelope and a containment constraint requiring the plume to remain within the aquifer zone over a 120-year simulation period. Three groups of scenarios were examined: well-placement sensitivity (A1–A3), production-assisted injection (B1–B3), and completion-design sensitivity (C1–C3). Among the baseline cases, A3 provided the best plume containment, with the most compact lateral footprint and smallest vertical plume spread, while A1 gave the highest total stored CO₂. Among the production-assisted cases, B2 was the most effective pressure-management option, producing the largest pressure reduction and a modest increase in total stored CO₂. Completion redesign generated the largest storage gains, increasing total stored CO₂ by about 28–33.3% relative to the corresponding baseline cases. Most scenarios maintained the plume confinement within the aquifer zone, although C1 showed localized upward CO₂ occurrence near the free-water level. Overall, the tested strategies improved storage performance, with A3 providing the best plume containment among the baseline cases, B2 delivering the strongest pressure-management benefit and increasing total stored CO₂ by approximately 3.93% relative to A2, and completion redesign producing the largest storage gains, increasing total stored CO₂ by about 28–33.3% relative to the corresponding baseline cases. Mineral trapping increased slightly in the completion-design cases, although it remained a minor component of total storage within the 120-year simulation period.
Co-Authors Eriska Eklezia Dwi Saputri Grandis, Garindia Ilham, Nanda Iskandar, Utomo Pratama Panuju