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Economic feasibility of carbon sequestration with enhanced gas recovery (CSEGR)

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  • Oldenburg, C.M
  • Stevens, S.H
  • Benson, S.M

Abstract

Prior reservoir simulation and laboratory studies have suggested that injecting carbon dioxide into mature natural gas reservoirs for carbon sequestration with enhanced gas recovery (CSEGR) is technically feasible. Reservoir simulations show that the high density of carbon dioxide can be exploited to favor displacement of methane with limited gas mixing by injecting carbon dioxide in low regions of a reservoir while producing from higher regions in the reservoir. Economic sensitivity analysis of a prototypical CSEGR application at a large depleting gas field in California shows that the largest expense will be for carbon dioxide capture, purification, compression, and transport to the field. Other incremental costs for CSEGR include: (1) new or reconditioned wells for carbon dioxide injection, methane production, and monitoring; (2) carbon dioxide distribution within the field; and, (3) separation facilities to handle eventual carbon dioxide contamination of the methane. Economic feasibility is most sensitive to wellhead methane price, carbon dioxide supply costs, and the ratio of carbon dioxide injected to incremental methane produced. Our analysis suggests that CSEGR may be economically feasible at carbon dioxide supply costs of up to US$ 4–12/t (US$ 0.20–0.63/Mcf). Although this analysis is based on a particular gas field, the approach is general and can be applied to other gas fields. This economic analysis, along with reservoir simulation and laboratory studies that suggest the technical feasibility of CSEGR, demonstrates that CSEGR can be feasible and that a field pilot study of the process should be undertaken to test the concept further.

Suggested Citation

  • Oldenburg, C.M & Stevens, S.H & Benson, S.M, 2004. "Economic feasibility of carbon sequestration with enhanced gas recovery (CSEGR)," Energy, Elsevier, vol. 29(9), pages 1413-1422.
    • Handle: RePEc:eee:energy:v:29:y:2004:i:9:p:1413-1422
    DOI: 10.1016/j.energy.2004.03.075
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    Cited by:

    1. Lucija Jukić & Domagoj Vulin & Valentina Kružić & Maja Arnaut, 2021. "Carbon-Negative Scenarios in High CO 2 Gas Condensate Reservoirs," Energies, MDPI, vol. 14(18), pages 1-11, September.
    2. Singh, A.K. & Goerke, U.-J. & Kolditz, O., 2011. "Numerical simulation of non-isothermal compositional gas flow: Application to carbon dioxide injection into gas reservoirs," Energy, Elsevier, vol. 36(5), pages 3446-3458.
    3. Adams, Benjamin M. & Kuehn, Thomas H. & Bielicki, Jeffrey M. & Randolph, Jimmy B. & Saar, Martin O., 2015. "A comparison of electric power output of CO2 Plume Geothermal (CPG) and brine geothermal systems for varying reservoir conditions," Applied Energy, Elsevier, vol. 140(C), pages 365-377.
    4. Saraf, Shubham & Bera, Achinta, 2021. "A review on pore-scale modeling and CT scan technique to characterize the trapped carbon dioxide in impermeable reservoir rocks during sequestration," Renewable and Sustainable Energy Reviews, Elsevier, vol. 144(C).
    5. Budzianowski, Wojciech Marcin, 2011. "Can ‘negative net CO2 emissions’ from decarbonised biogas-to-electricity contribute to solving Poland’s carbon capture and sequestration dilemmas?," Energy, Elsevier, vol. 36(11), pages 6318-6325.
    6. Patel, Milan J. & May, Eric F. & Johns, Michael L., 2016. "High-fidelity reservoir simulations of enhanced gas recovery with supercritical CO2," Energy, Elsevier, vol. 111(C), pages 548-559.
    7. Cui, Guodong & Zhang, Liang & Ren, Bo & Enechukwu, Chioma & Liu, Yanmin & Ren, Shaoran, 2016. "Geothermal exploitation from depleted high temperature gas reservoirs via recycling supercritical CO2: Heat mining rate and salt precipitation effects," Applied Energy, Elsevier, vol. 183(C), pages 837-852.
    8. Cui, Guodong & Pei, Shufeng & Rui, Zhenhua & Dou, Bin & Ning, Fulong & Wang, Jiaqiang, 2021. "Whole process analysis of geothermal exploitation and power generation from a depleted high-temperature gas reservoir by recycling CO2," Energy, Elsevier, vol. 217(C).
    9. Michel Moreaux & Jean-Pierre Amigues & Gerard van der Meijden & Cees Withagen, "undated". "Carbon Capture: Storage vs. Utilization," Tinbergen Institute Discussion Papers 22-041/VIII, Tinbergen Institute.
    10. Budzianowski, Wojciech M., 2012. "Value-added carbon management technologies for low CO2 intensive carbon-based energy vectors," Energy, Elsevier, vol. 41(1), pages 280-297.
    11. Jo Tan & Guy Allinson & Yildiray Cinar, 2013. "A Techno-Economic Analysis of Coupling Enhanced Hydrocarbon Recovery and CO2 Storage in Gas Condensate Reservoirs," Energy and Environment Research, Canadian Center of Science and Education, vol. 3(2), pages 1-73, December.
    12. Justin Ezekiel & Diya Kumbhat & Anozie Ebigbo & Benjamin M. Adams & Martin O. Saar, 2021. "Sensitivity of Reservoir and Operational Parameters on the Energy Extraction Performance of Combined CO 2 -EGR–CPG Systems," Energies, MDPI, vol. 14(19), pages 1-21, September.
    13. Ma, Lei & Zhou, Lei & Mbadinga, Serge Maurice & Gu, Ji-Dong & Mu, Bo-Zhong, 2018. "Accelerated CO2 reduction to methane for energy by zero valent iron in oil reservoir production waters," Energy, Elsevier, vol. 147(C), pages 663-671.
    14. Ezekiel, Justin & Ebigbo, Anozie & Adams, Benjamin M. & Saar, Martin O., 2020. "Combining natural gas recovery and CO2-based geothermal energy extraction for electric power generation," Applied Energy, Elsevier, vol. 269(C).
    15. Luo, Feng & Xu, Rui-Na & Jiang, Pei-Xue, 2013. "Numerical investigation of the influence of vertical permeability heterogeneity in stratified formation and of injection/production well perforation placement on CO2 geological storage with enhanced C," Applied Energy, Elsevier, vol. 102(C), pages 1314-1323.

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