A Potential Parameter for A Non-Darcy Form of Two-Phase Flow Behaviour, Compressibility Related

  • Authors

    • Bashir Busahmin
    • Brij Maini
    2018-06-21
    https://doi.org/10.14419/ijet.v7i3.3.14504
  • Capillary number, Depletion test, Foamy oil property, Solution gas drive.

  • Abstract

    Numerous scientists did their studies and conducted various laboratory experiments related to a non-Darcy behavior of a two-phase flow for the past thirty years, and made an effort to clarify the behavior. Non-Darcy flow behavior, phenomena occurred in primary recovery method of reservoirs that have an API degree gravity of less than 20. It was confirmed that it results in greater production. The compressibility of foam fits to be the one of the general fundamental factor that directs the lifetime of a non-Darcy form of two phase flow behavior or also is known as the foamy oil.  In the process of usual drive depletion, foamy oil featured of low production GOR and high daily production rate. Foamy oil is more compressible than conventional solution gas due to the oil that gas dispersed in it; as a result, oil formation volume factor is much higher than that in conventional oil. This paper represents a laboratory data followed by some of the analysis related to the properties of non-Darcy form of two phase flow and that is the compressibility parameter. The experimental results showed that at different saturation pressures and at a room temperature, the trends fit the expected behavior above the saturation pressures. Moreover, the measurements of live oil compressibility were also attempted below the saturation pressures. It was concluded that other properties such as the viscosity is added a significant effect rather than compressibility in the behavior of what so called  foamy oil compared to the presence or absence of asphaltenes and other polar oil components.

     

     

  • References

    1. [1] B.S. Busahmin & B.B. Maini (2011),Comparison between Foamy mineral oil and crude Oil under Solution - gas drive, in: Oil and gas conference, Calgary, Alberta, Canada.

      [2] L. Xiao & G. Zhao (2013), Integrated Study of Foamy Oil Flow and Wormhole Structure in CHOPS through Transient Pressure Analysis, in: SPE Heavy Oil Conference-Canada, Society of Petroleum Engineers.

      [3] K.R. Rao, D.P. Rao, C. Venkateswarlu (2009), Soft sensor based nonlinear control of a chaotic reactor, IFAC Proceedings Volumes, 42, 537-543.

      [4] R.R. Karri, J.N. Sahu (2018), Modeling and optimization by particle swarm embedded neural network for adsorption of zinc (II) by palm kernel shell based activated carbon from aqueous environment, Journal of Environmental Management, 206, 178-191.

      [5] R.R. Karri, J.N. Sahu, N.S. Jayakumar (2017), Optimal isotherm parameters for phenol adsorption from aqueous solutions onto coconut shell based activated carbon: Error analysis of linear and non-linear methods, Journal of the Taiwan Institute of Chemical Engineers, 80, 472-487.

      [6] K.R. Rao, T. Srinivasan, C. Venkateswarlu (2010), Mathematical and kinetic modeling of biofilm reactor based on ant colony optimization, Process Biochemistry, 45,961-972.

      [7] B. Busahmin, B. Maini, R.R. Karri, M. Sabet (2017), Studies on the Stability of the Foamy Oil in Developing Heavy Oil Reservoirs, Defect and Diffusion Forum, 371,111-116.

      [8] J.G. Sheng, B.B. Maini, W.S. Tortike (1995), A Non-Equilibrium Model to Calculate Foamy Oil Properties, in: Annual Technical Meeting, Petroleum Society of Canada.

      [9] B.B. Maini & B. Busahmin (2010), Foamy oil flow and its role in heavy oil production, in: AIP Conference Proceedings, AIP, 103-108.

      [10] X. Zhang, X. Wu, J. Zhang, R. Wang, L. Wang, R. Zhao, K. Liu (2012), A New Modeling Approach for Bubble Growth in Foamy Oil, Petroleum Science and Technology, 30, 1498-1507.

      [11] B. Busahmin, B. Maini, U.H.B.H. Hasan (2017), Influence of Compressibility on Heavy/FoamyOil Flow, IOSR Journal of Engineering, 07, 18-28.

      [12] M. Tavallali, B.B. Maini, T.G. Harding, B.S. Busahmin 2012, Assessment of SAGD Well Configuration Optimization in Lloydminster Heavy Oil Reserve, in: SPE/EAGE European Unconventional Resources Conference and Exhibition, Society of Petroleum Engineers.

      [13] consecutive year, as well as the best teacher from the peers. Dr Bashir is a registered member in APEGGA and a member in Scince technology. Finally, received a teaching exxcellence award in 2013 fro the Southrn Alberta Institute of Technology as well as a nomination of the awards from the university Technology Brunei.

      [14] Y. Shi, X. Li, D. Yang (2016), Nonequilibrium Phase Behavior of Alkane Solvent(s) –CO2–Heavy Oil Systems under Reservoir Conditions, Industrial & Engineering Chemistry Research, 55, 2860-2871.

      [15] R. Kumar, J. Mahadevan (2012), Well-performance relationships in heavy-foamy-oil reservoirs, SPE Production & Operations, 27, 94-105.

      [16] X. Sun, Y. Zhang, S. Wang, Z. Song, P. Li, C. Wang (2018), Experimental study and new three-dimensional kinetic modeling of foamy solution-gas drive processes, Scientific reports, 8, 4369.

      [17] G.E. Smith, Fluid Flow and Sand Production in Heavy-Oil Reservoirs Under Solution-Gas Drive, SPE Production Engineering, 3 (1988) 169-180.

      [18] E.L. Claridge (1994), A proposed model and mechanism for anomalous foamy heavy oil behavior.

      [19] R.G. Santos, W. Loh, A.C. Bannwart, O.V. Trevisan (2014), An overview of heavy oil properties and its recovery and transportation methods, Brazilian Journal of Chemical Engineering, 31, 571-590.

      [20] B.S. Abusahmin, R.R. Karri, B.B. Maini (2017), Influence of fluid and operating parameters on the recovery factors and gas oil ratio in high viscous reservoirs under foamy solution gas drive, Fuel, 197, 497-517.

      [21] B. Busahmin, E.-S.M. Zahran, B. Maini (2016), Application of Foamy Mineral Oil Flow under Solution Gas Drive toa Field Crude Oil, The International Journal of Engineering and Science (IJES), 5, 48-58.

  • Downloads

  • How to Cite

    Busahmin, B., & Maini, B. (2018). A Potential Parameter for A Non-Darcy Form of Two-Phase Flow Behaviour, Compressibility Related. International Journal of Engineering & Technology, 7(3.3), 126-131. https://doi.org/10.14419/ijet.v7i3.3.14504

    Received date: 2018-06-21

    Accepted date: 2018-06-21

    Published date: 2018-06-21