1887

Abstract

Summary

Gas condensate reservoirs exhibit complex behaviour when they are produced below dew point pressure under isothermal conditions; this is due to the appearance of a two-phase gas-condensate in the near wellbore region. In addition, at high flow rates in the near wellbore region, inertial forces counteract with velocity dependence of relative permeability. This behaviour can be resolved using local grid refinements; however, the computation burden becomes excessive, especially in a full field simulation. Alternatively pseudo-pressure approach can be used which iteratively solves a non-linear equation at each integration point, and is also computationally expensive. Furthermore, the conventional pseudo-pressure method lacks efficient coupling of the complex interaction of fluid composition, liquid dropout rate, gas-oil relative permeability, gas-oil interfacial tensions, and non-Darcy flow effects. Development of a computationally efficient and accurate approach to model near wellbore phenomena without increasing grid resolution is presented. An adaptive piecewise representation of pseudo-pressure is used, replacing non-linear equation solved at each integration point, thus drastically reducing computational cost without undue loss of accuracy. Non-Darcy flow effects and interaction of rock and fluid properties are captured in the pseudo-pressure integrand in a unified manner. The results are validated against a commercial simulator, and fine grid results, which demonstrate the accuracy and consistency of the approach. Finally the efficiency of the approach is demonstrated by simulating a giant gas-condensate model with thousands of wells and millions of cells, all solved on a massively parallel computer.

Loading

Article metrics loading...

/content/papers/10.3997/2214-4609.201802126
2018-09-03
2024-04-19
Loading full text...

Full text loading...

References

  1. Afidick, D., Kaczorowski, N.J., and Bette, S.
    [1994] Production Performance of a Retrograde Gas Reservoir: A Case Study of the Arun Field.Society of Petroleum Engineers, doi:10.2118/28749‑MS.
    https://doi.org/10.2118/28749-MS [Google Scholar]
  2. Blom, S.M.P., and Hagoort, J.
    [1998] How to Include the Capillary Number in Gas Condensate Relative Permeability Functions?Society of Petroleum Engineers, doi:10.2118/49268‑MS.
    https://doi.org/10.2118/49268-MS [Google Scholar]
  3. Chang, M.M., Maerefat, N.L., Tomutsa, L., and Honarpour, M.M.
    [1988] Evaluation and Comparison of Residual Oil Saturation Determination Techniques.Society of Petroleum Engineers, doi:10.2118/14887‑PA.
    https://doi.org/10.2118/14887-PA [Google Scholar]
  4. ChaudharyA.U.
    [2003] Chapter: Overall skin effects and impact on gas well performance, in Gas Well Testing Handbook, Gulf Professional Publishing, 664–693.
    [Google Scholar]
  5. Coats, K.H.
    [1980] An Equation of State Compositional Model.Society of Petroleum Engineers, doi: 10.2118/8284-PA.
    [Google Scholar]
  6. Dacun, Li, and Thomas, W.E.
    [2001] Literature review on Correlations of the non-Darcy Coefficient.SPE 70015, Texas USA.
    [Google Scholar]
  7. Dake, L.P.
    [1978] Fundamentals of Reservoir Engineering.The Netherlands, Elsevier Science BV, Amsterdam, 256–258.
    [Google Scholar]
  8. DaliHou, YangXiao, YiPan, LeiSun, and KaiLi
    [2016] Experiment and Simulation Study on the Special Phase Behavior of Huachang Near-Critical Condensate Gas Reservoir Fluid.Journal of Chemistry, Volume 2016, Article ID 2742696.
    [Google Scholar]
  9. Dogru, A.H. et al.
    [2009] A Next-Generation Parallel Reservoir Simulator for Giant Reservoirs.Proceedings of the SPE Reservoir Simulation Symposium, the Woodlands, Texas, USA, 2-4 February, SPE, SPE-119272.
    [Google Scholar]
  10. Eilerts, C.K., Sumner, E.F., and Potts, N.L.
    [1965]. Integration of Partial Differential Equation for Transient Radial Flow of Gas-Condensate Fluids in Porous Structures.Society of Petroleum Engineers, doi:10.2118/716‑PA.
    https://doi.org/10.2118/716-PA [Google Scholar]
  11. Evinger, H. H., and Muskat, M
    [1942] Calculation of Theoretical Productivity Factor. Society of Petroleum Engineers, doi: 10.2118/942126‑G.
    https://doi.org/10.2118/942126-G [Google Scholar]
  12. Fevang, ∅. and Whitson, C.H.
    [1995] Modelling Gas-Condensate Well Deliverability.Proceedings of the SPE Annual Technical Conference and Exhibition (SPE 30714), Dallas, USA.
    [Google Scholar]
  13. [1997] Generalized pseudo-pressure well treatment in reservoir simulation.
    [Google Scholar]
  14. Fetkovich, M.J.
    [1973] The Isochronal Testing of Oil Wells.Society of Petroleum Engineers, doi:10.2118/4529‑MS.
    https://doi.org/10.2118/4529-MS [Google Scholar]
  15. Fussell, D.D.
    [1973] Single-Well Performance Predictions for Gas Condensate Reservoirs.Society of Petroleum Engineers, doi:10.2118/4072‑PA.
    https://doi.org/10.2118/4072-PA [Google Scholar]
  16. Gondouin, M., Iffly, R., and Husson, J.
    [1967] An Attempt to Predict the Time Dependence of Well Deliverability in Gas Condensate Fields.Society of Petroleum Engineers (SPE). doi:10.2118/1478‑PA.
    https://doi.org/10.2118/1478-PA [Google Scholar]
  17. Jacoby, R.H. and Yarbrough, L.
    [1967] PVT measurements on petroleum fluids and their uses.Ind. and Eng. Chem.59 (10), 48–62.
    [Google Scholar]
  18. Jamiolahmady, M., Danesh, A., Rezaei, A., Ataei, A., and Sohrabi, M.S.
    [2005] Calculation of productivity of a gas-condensate well: application of skin with rate dependent pseudo-pressure.SPE European Formation Damage Conference (SPE-94718-MS), doi:10.2118/94718‑MS.
    https://doi.org/10.2118/94718-MS [Google Scholar]
  19. Kniazeff, V.J., and Naville, S.A.
    [1965] Two-Phase Flow of Volatile Hydrocarbons.Society of Petroleum Engineers, doi:10.2118/962‑PA.
    https://doi.org/10.2118/962-PA [Google Scholar]
  20. Lombard, J.M., Longeron, D.G., and Kalaydjian, F.J.M.
    [2000] Influence of Connate Water and Condensate Saturation on Inertial Effects in Gas/Condensate Reservoirs.Society of Petroleum Engineers, doi:10.2118/65430‑PA.
    https://doi.org/10.2118/65430-PA [Google Scholar]
  21. Mohan, J., Pope, G.A., and Sharma, M.M.
    [2009] Effect of Non-Darcy Flow on Well Productivity of a Hydraulically Fractured Gas-Condensate Well.Society of Petroleum Engineers, doi:10.2118/103025‑PA.
    https://doi.org/10.2118/103025-PA [Google Scholar]
  22. Mott, R.
    [1999] Calculating well deliverability in Gas Condensate Reservoirs.Proceedings of 10th European Symposium on Improved Oil Recovery, Brighton, UK.
    [Google Scholar]
  23. Newman, M.S., and Yin, X.
    [2011]. The Effect of Pore Heterogeneity on Non-Darcy Flow by Lattice Boltzmann Simulation.Society of Petroleum Engineers, doi:10.2118/146689‑MS.
    https://doi.org/10.2118/146689-MS [Google Scholar]
  24. O’Dell, H.G.
    [1967] Successfully Cycling a Low-Permeability, High-Yield Gas Condensate Reservoir.Society of Petroleum Engineers, doi:10.2118/1495‑PA.
    https://doi.org/10.2118/1495-PA [Google Scholar]
  25. Peaceman, D.
    [1978] Interpretation of Well-Block Pressures in Numerical Reservoir Simulation, Society of Petroleum Engineers Journal of AIME, 183–192.
    [Google Scholar]
  26. Singh, K. and Whitson, C.H.
    [2010] Gas-Condensate Pseudopressure in layered reservoirs, SPE reservoir evaluation and engineering (SPE-117930-PA), 13(02), 203–213.
    [Google Scholar]
  27. WhitakerS.
    [1996] The Forchheimer equation: A theoretical development.Transport in Porous Media, 25(1), 27–61.
    [Google Scholar]
  28. Whitson, C.H., Fevang, ∅., and Sævareid, A.
    [2003] Gas Condensate Relative Permeability for Well Calculations.Transport in Porous Media, 52(2) 1573–1634.
    [Google Scholar]
http://instance.metastore.ingenta.com/content/papers/10.3997/2214-4609.201802126
Loading
/content/papers/10.3997/2214-4609.201802126
Loading

Data & Media loading...

This is a required field
Please enter a valid email address
Approval was a Success
Invalid data
An Error Occurred
Approval was partially successful, following selected items could not be processed due to error