| Peer-Reviewed

Potential of a Locally Made ASP Formulation Ogbonor (Irvingia Gabonensis) in Enhanced Oil Recovery Processes

Received: 29 March 2017     Accepted: 30 March 2017     Published: 11 April 2017
Views:       Downloads:
Abstract

The quest for techniques to recover the remaining 60–80% of the original oil in place (OOIP) left upon conventional oil recovery methods has become imperative. Alkaline–surfactant–polymer (ASP) flooding has emerged as one of the most promising and widely applicable techniques due to its significant improvement on the displacement and sweep efficiency. A number of the attempts has been devoted to investigating the combination of up to three substances to form the appropriate ASP system for a given application, which has been without a number of technical challenges. This paper reviews the possibility of employing an appropriately engineered synthesis of an ASP substance which incorporates all the three components in one. Research has been conducted into the suitability of an ASP system formulated using locally available and thus economically viable raw materials (Ogbonor seeds, Irvingia gabonensis, potash, and salt). The study shows the best level of salinity needed for the retention of the polymer gel viscosity is 30g/l and the maximum viscosity of the polymer solution is 1.086, in the absence of additives. This brought to a conclusion that the chosen additive (potash) does not have a significant effect on the polymer solution that will result in highest viscosity which enhances a good percentage of oil recovery. Polynomial models relating the resulting polymer viscosity with concentration and salinity have been developed, applicable for predicting polymer viscosity at different concentrations of salt and additive.

Published in American Journal of Chemical Engineering (Volume 5, Issue 3-1)

This article belongs to the Special Issue Oil Field Chemicals and Petrochemicals

DOI 10.11648/j.ajche.s.2017050301.11
Page(s) 1-9
Creative Commons

This is an Open Access article, distributed under the terms of the Creative Commons Attribution 4.0 International License (http://creativecommons.org/licenses/by/4.0/), which permits unrestricted use, distribution and reproduction in any medium or format, provided the original work is properly cited.

Copyright

Copyright © The Author(s), 2017. Published by Science Publishing Group

Keywords

Alkaline, Surfactant, Polymer, Oil Recovery, Viscosity, Ogbonor, Salinity, Modeling

References
[1] Musharova, Darya (2010). Enhanced Oil Recovery Using the Alkaline-Surfactant-Polymer (ASP). Texas A&M University.
[2] Sarka, S. (2012). Evaluation of Alkaline, Surfactant and Polymer Flooding for Enhanced Oil Recovery in the Norne E-segment Based on Applied Reservoir Simulation, M. Sc. Thesis, Norwegian University of Science and Technology.
[3] Liu S., Zhang D. L., Yan W., Puerto M., Hirasaki G. J., Miller C. A. (2008). Favourable Attributes of Alkali-Surfactant-polymer flooding, SPE J. 13 (1): 5-16. SPe-99744-PA. doi: 10.2118/99744-PA.
[4] Hongyan W. and Brian M. (2013). Development of a new surfactant-polymer system and its implementation in Dagang oilfield. Geological and Scientific Research Institute, Shengli Oilfield SINOPEC, Dongying 257015, PR China. EnProTech, Houston, USA.
[5] Martins, F. D., (1986) ‘Design and Implementation of a Polymer Flood’, South-Western Petroleum short course proc. 33rd Annual South-Western Short course, Lubbock, 23rd – 24th April.
[6] Liu, S., Li, R. F., Miller, C. A., & Hirasaki, G. J. (2008, January 1). ASP Process: Wide Range of Conditions for Good Recovery. Society of Petroleum Engineers. doi: 10.2118/113936-MS.
[7] Seright, R. S. 2009b. Use of Polymers to Recover Viscous Oil from Unconventional Reservoirs. First Annual Report, U.S. Department of Energy, DOE Contract No.: DE-NT0006555, US DOE, Washington, DC (October 2009).
[8] Seright, R. S. and Liang, J. 1994. A Survey of Field Applications of Gel Treatments for Water Shutoff. Paper SPE 26991 presented at the SPE Latin American and Caribbean Petroleum Engineering Conference, Buenos Aires, 27-29April. doi: 10.2118/26991-MS.
[9] Seright, R. S., Fan, T., Wavrik, K., and Balaban, R. C. 2010. New Insights into Polymer Rheology in Porous Media. Paper SPE 129200 presented at the SPE Improved OilRecovery Symposium, Tulsa, Oklahoma, USA, 24-28 April. doi: 10.2118/129200-MS.
[10] Seright, R. S., Seheult, M., Kelco, C. P., and Talashek, T. 2009c. Injectivity Characteristics of EOR Polymers. SPE Res Eval & Eng 12 (5): 783-792. SPE-115142-PA. doi: 10.2118/115142-PA.
[11] Zhang Y., Xie X. and Morrow N. R, (2007). “Waterflood Performance by Injection of Brine with Different Salinity for Reservoir Cores”, Paper SPE 109849, presented at the 2007 SPE Annual Technical Conference and Exhibition, Anaheim, California, November 11-14, 2007.
[12] William, C. L., (1996) ‘Standard Handbook of Petroleum and Natural Gas Engineering’ Copyright©, 1996 by Gulf Publishing Company Houston, Texas. Pp319-325.
[13] Hirasaki, G. J., Miller C. A., and Puerto M. (2008) Recent Advances in Surfactant EOR, Paper SPE-115386-MS, SPE Annual Technical Conference and Exhibition, 21-24 September, Denver, Colorado, USA.
[14] Khaled A. E., Isa M. T., Muhammad T. F. Abo-Jabal A., (2011) "Development of a New Polymeric Surfactant for Chemical Enhanced Oil Recovery", Petroleum Science and Technology 29(14):1521-1528.
[15] Voronov S, Tokarev V, Datsyuk V, Seredyuk V, Bednarska O, Oduola K, Adler H, Pushke C, Pich A, Wagenknecht U (2000), Polyperoxidic Surfactants for Interface Modification and Compatibilization of Polymer Colloidal Systems. 2. Design of Compatibilizing Layers, J. Applied Polym. Sci., 76, pp. 1217-1227.
[16] Voronov S, Tokarev V, Oduola K and Lastukhin Yu (2000), Polyperoxidic Surfactants for Interface Modification and Compatibilization of Polymer Colloidal Systems. 1. Synthesis and Characterization, J. Applied Polym. Sci., 76, pp. 1228-1239.
[17] Oduola MK (2009), Design of Compatibilizing Interfacial Polymer Layers Using a Macroinitiator, Advanced Materials Research, Trans Tech Publications, Switzerland, Vols. 62-64, pp. 311-316.
[18] Oduola K, Tokarev V, Donchak V, Ripak L and Voronov S, (2002), Synthesis and Initiating Properties of Nitrogen-Containing Peroxide Oligomers, Issues of Chemistry & Chemical Engineering, № 3, pp. 103-108.
[19] Oduola MK, Tokarev V., Voronov S., (2007), Polymer Modification of Mineral Surface Using Peroxide-Containing Oligomers, Advanced Materials Research, Trans Tech Publications, Switzerland, Vols. 18-19, pp. 219-224.
[20] Bai, B., Huang, F., Liu, Y., Seright R. S., and Wang, Y (2008) ‘Case Study on Performed Particle Gel for In-depth Fluid Diversion’ Paper SPE 113997, presented at SPE/DOE Improved Oil Recovery Symposium, Tulsa, Oklahoma. April, Pp 19-23.
[21] Rosen M. J. and Kunjappu J. T. (2012). Surfactants and Interfacial Phenomena (4thed.), Hoboken, New Jersey.
[22] Martins, F. D., (1986) ‘Design and Implementation of a Polymer Flood’, South-Western Petroleum short course proc. 33rd Annual South-Western Short course, Lubbock, 23rd – 24th April, 1986.
[23] Obah, B., Chukwu, O. and Onyche, T. D. (1998) ‘Phase Behavior of Nigerian Oil/Water by the Addition of Surfactant/Co-Surfactants’ Seibnish: 23. D 38678 Clauster Zeller, Germany.
[24] Tang, G. Q. and Morrow, N. R.: ‘Influence of Brine Composition and Fines Migration on Crude Oil/Brine?rock Interactions and Oil Recovery’, Journal of Petroleum Science and Engineering, 24,1999, pp-111.
[25] Littman, J. ‘Polymer Flooding: Development in Petroleum Science’ Volume 24. Amsterdan: Elsevier Inc, 1988.
[26] Moradi-Araghi, A. and P. H. Doe (1987), ‘Development and Evaluation of EOR Polymers, SPE: RE 2(4), Pp461-467.
[27] Zhang, Y. and Morrow, N. R.: “Comparison of Secondary and Tertiary Recovery with Chang in Injection Brine Composition for Crude Oil/Sandstone Combinations”, Paper SPE 99757, presented at the SPE/DOE Symposium on Improved Oil Recovery, Tulsa, Oklahoma, April 22-26, 2006.
[28] National Petroleum Council (NPC), 1984: ‘Enhanced Oil Recovery’, Washington D.C., US Dept of Energy, June, 1984. P206.
Cite This Article
  • APA Style

    Koyejo Oduola, Nyemachi Oriji. (2017). Potential of a Locally Made ASP Formulation Ogbonor (Irvingia Gabonensis) in Enhanced Oil Recovery Processes. American Journal of Chemical Engineering, 5(3-1), 1-9. https://doi.org/10.11648/j.ajche.s.2017050301.11

    Copy | Download

    ACS Style

    Koyejo Oduola; Nyemachi Oriji. Potential of a Locally Made ASP Formulation Ogbonor (Irvingia Gabonensis) in Enhanced Oil Recovery Processes. Am. J. Chem. Eng. 2017, 5(3-1), 1-9. doi: 10.11648/j.ajche.s.2017050301.11

    Copy | Download

    AMA Style

    Koyejo Oduola, Nyemachi Oriji. Potential of a Locally Made ASP Formulation Ogbonor (Irvingia Gabonensis) in Enhanced Oil Recovery Processes. Am J Chem Eng. 2017;5(3-1):1-9. doi: 10.11648/j.ajche.s.2017050301.11

    Copy | Download

  • @article{10.11648/j.ajche.s.2017050301.11,
      author = {Koyejo Oduola and Nyemachi Oriji},
      title = {Potential of a Locally Made ASP Formulation Ogbonor (Irvingia Gabonensis) in Enhanced Oil Recovery Processes},
      journal = {American Journal of Chemical Engineering},
      volume = {5},
      number = {3-1},
      pages = {1-9},
      doi = {10.11648/j.ajche.s.2017050301.11},
      url = {https://doi.org/10.11648/j.ajche.s.2017050301.11},
      eprint = {https://article.sciencepublishinggroup.com/pdf/10.11648.j.ajche.s.2017050301.11},
      abstract = {The quest for techniques to recover the remaining 60–80% of the original oil in place (OOIP) left upon conventional oil recovery methods has become imperative. Alkaline–surfactant–polymer (ASP) flooding has emerged as one of the most promising and widely applicable techniques due to its significant improvement on the displacement and sweep efficiency. A number of the attempts has been devoted to investigating the combination of up to three substances to form the appropriate ASP system for a given application, which has been without a number of technical challenges. This paper reviews the possibility of employing an appropriately engineered synthesis of an ASP substance which incorporates all the three components in one. Research has been conducted into the suitability of an ASP system formulated using locally available and thus economically viable raw materials (Ogbonor seeds, Irvingia gabonensis, potash, and salt). The study shows the best level of salinity needed for the retention of the polymer gel viscosity is 30g/l and the maximum viscosity of the polymer solution is 1.086, in the absence of additives. This brought to a conclusion that the chosen additive (potash) does not have a significant effect on the polymer solution that will result in highest viscosity which enhances a good percentage of oil recovery. Polynomial models relating the resulting polymer viscosity with concentration and salinity have been developed, applicable for predicting polymer viscosity at different concentrations of salt and additive.},
     year = {2017}
    }
    

    Copy | Download

  • TY  - JOUR
    T1  - Potential of a Locally Made ASP Formulation Ogbonor (Irvingia Gabonensis) in Enhanced Oil Recovery Processes
    AU  - Koyejo Oduola
    AU  - Nyemachi Oriji
    Y1  - 2017/04/11
    PY  - 2017
    N1  - https://doi.org/10.11648/j.ajche.s.2017050301.11
    DO  - 10.11648/j.ajche.s.2017050301.11
    T2  - American Journal of Chemical Engineering
    JF  - American Journal of Chemical Engineering
    JO  - American Journal of Chemical Engineering
    SP  - 1
    EP  - 9
    PB  - Science Publishing Group
    SN  - 2330-8613
    UR  - https://doi.org/10.11648/j.ajche.s.2017050301.11
    AB  - The quest for techniques to recover the remaining 60–80% of the original oil in place (OOIP) left upon conventional oil recovery methods has become imperative. Alkaline–surfactant–polymer (ASP) flooding has emerged as one of the most promising and widely applicable techniques due to its significant improvement on the displacement and sweep efficiency. A number of the attempts has been devoted to investigating the combination of up to three substances to form the appropriate ASP system for a given application, which has been without a number of technical challenges. This paper reviews the possibility of employing an appropriately engineered synthesis of an ASP substance which incorporates all the three components in one. Research has been conducted into the suitability of an ASP system formulated using locally available and thus economically viable raw materials (Ogbonor seeds, Irvingia gabonensis, potash, and salt). The study shows the best level of salinity needed for the retention of the polymer gel viscosity is 30g/l and the maximum viscosity of the polymer solution is 1.086, in the absence of additives. This brought to a conclusion that the chosen additive (potash) does not have a significant effect on the polymer solution that will result in highest viscosity which enhances a good percentage of oil recovery. Polynomial models relating the resulting polymer viscosity with concentration and salinity have been developed, applicable for predicting polymer viscosity at different concentrations of salt and additive.
    VL  - 5
    IS  - 3-1
    ER  - 

    Copy | Download

Author Information
  • Department of Chemical Engineering, University of Port Harcourt, Port Harcourt, Nigeria

  • Department of Chemical Engineering, University of Port Harcourt, Port Harcourt, Nigeria

  • Sections