Journal of Canadian Petroleum Technology
Volume 50, Number 3, March 2011, pp. 57-64

SPE-133298-PA

Numerical Investigation of Potential Injection Strategies To Reduce Shale Barrier Impacts on SAGD Process

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DOI  More information 10.2118/133298-PA http://dx.doi.org/10.2118/133298-PA

Citation

  • Li, W., Qui, F., Mamora, D.D., and Li, Y. 2011. Numerical Investigation of Potential Injection Strategies To Reduce Shale Barrier Impacts on SAGD Process. J Can Pet Technol  50 (3): 57-64. SPE-133298-PA. doi: 10.2118/133298-PA.

Discipline Categories

  • 6.4 Primary and Enhanced Recovery Processes
  • 6.4.5 Thermal Methods (e.g.,Steamflood, Cyclic Steam, THAI, Combustion)
  • 6.4.6 Chemical Flooding Methods Methods (e.g., Polymer, Solvent, Nitrogen, Immiscible CO2, Surfactant, Vapex)

Keywords

  • SAGD, shale barrier, solvent coinjection, top injector application, Athabasca

Summary

It is well known that shale barriers significantly reduce steam-assisted gravity drainage (SAGD) performance in Athabasca fields. An extensive 2D simulation study shows that the flow resistance at the end of shale barriers and the extra heat absorbed by the residual water inside the unproductive shale barrier are the main reasons for the shale barrier effects. Long continuous shale barriers located vertically above or near the wellbore delay production performance significantly.

We investigated potential strategies, including solvent coinjection, top injector application, or a combination of both, to reduce the shale barrier impacts. Solvent in the vapour phase can pass through the narrow flow path at the end of a shale barrier. Meanwhile, because the phase condenses from vapour to liquid, solvent efficiently reduces the flow resistance of the shale barrier. Liquid solvent coinjection can accelerate the near-wellbore flow and reduce the residual oil saturation at the wellbore vicinity. Coinjecting a multicomponent solvent can flush out the oil at different areas with different drainage mechanisms from vaporized and liquid components. Additional injector application at the top of the reservoir results in only marginal improvement.

© 2011. Society of Petroleum Engineers

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History

  • Original manuscript received: 29 June 2010
  • Meeting paper published: 25 May 2010
  • Revised manuscript received: 5 January 2011
  • Manuscript approved: 10 January 2011
  • Version of record: 1 March 2011