Advanced Search

Indexed by SCI、CA、РЖ、PA、CSA、ZR、etc .

Volume 28 Issue 5
Oct 2017
Turn off MathJax
Article Contents
Journal of Earth Science  > 2017  >  28(5): 835-841.
Shehzad Ahmed, Khaled Abdalla Elraies, Jalal Foroozesh, Siti Rohaida Bt Mohd Shafian, Muhammad Rehan Hashmet, Ivy Chai Ching Hsia, Abdullah Almansour. Experimental Investigation of Immiscible Supercritical Carbon Dioxide Foam Rheology for Improved Oil Recovery. Journal of Earth Science, 2017, 28(5): 835-841. doi: 10.1007/s12583-017-0803-z
Citation: Shehzad Ahmed, Khaled Abdalla Elraies, Jalal Foroozesh, Siti Rohaida Bt Mohd Shafian, Muhammad Rehan Hashmet, Ivy Chai Ching Hsia, Abdullah Almansour. Experimental Investigation of Immiscible Supercritical Carbon Dioxide Foam Rheology for Improved Oil Recovery. Journal of Earth Science, 2017, 28(5): 835-841. doi: 10.1007/s12583-017-0803-z
shu

Experimental Investigation of Immiscible Supercritical Carbon Dioxide Foam Rheology for Improved Oil Recovery

doi: 10.1007/s12583-017-0803-z
  • 1.

    Petroleum Engineering Department, Universiti Teknologi PETRONAS, Seri Iskandar 32610, Malaysia

  • 2.

    PETRONAS Research Sdn Bhd, Bangi 43000, Malaysia

  • 3.

    Department of Petroleum Engineering, Petroleum Institute, 2533 Abu Dhabi, UAE

  • 4.

    National Center for Oil & Gas Technology, King Abdulaziz City for Science and Technology, 11442 Riyadh, Saudi Arabia

More Information
  • Corresponding author: Shehzad Ahmed, shehzadahmed904@yahoo.com
  • Received Date: 11 Jun 2017
  • Accepted Date: 10 Aug 2017
  • Publish Date: 01 Oct 2017
    Abstract
  • This paper presents the rheological behaviour of supercritical CO2 (sCO2) foam at reservoir conditions of 1 500 psi and 80 ℃. Different commercial surfactants were screened and utilized in order to generate a fairly stable CO2 foam. Mixed surfactant system was also introduced to generate strong foam. Foam rheology was studied for some specific foam qualities using a high pressure high temperature (HPHT) foam loop rheometer. A typical shear thinning behaviour of the foam was observed and a significant increase in the foam viscosity was noticed with the increase of foam quality until 85%. A desired high apparent viscosity with coarse texture was found at 85% foam quality. Foam visualization above 85% showed an unstable foam due to extremely thin lamella which collapsed and totally disappeared in the loop rheometer. Below 52%, a non-homogenous and unstable foam was found having low viscosity with some liquid accumulation at the bottom of the circulation loop. This research has demonstrated rheology of sCO2 foams at different qualities at HPHT to obtain optimal foam quality region for immiscible CO2 foam co-injection process.

     

    • FullText(HTML)
  • loading
    • References(43)
  • Abbaszadeh, M. , Kazemi Nia Korrani, A. , Lopez-Salinas, J. L. , et al. , 2014. Experimentally-Based Empirical Foam Modeling. In: SPE Improved Oil Recovery Symposium, Society of Petroleum Engineers, Tulsa, Oklahoma, USA https: //www. mendeley. com/research-papers/experimentallybased-empirical-foam-modeling/
    Ahmed, S., Elraies, K. A., Tan, I. M., et al., 2017. Experimental Investigation of Associative Polymer Performance for CO2 Foam Enhanced Oil Recovery. Journal of Petroleum Science and Engineering, 157: 971-979. https://doi.org/10.13039/501100005710
    Alquriaishi, A. A., Shokir, E. M. E. M., 2011. Experimental Investigation of Miscible CO2 Flooding. Petroleum Science and Technology, 29(19): 2005-2016. https://doi.org/10.1080/10916461003662976
    Cao, R. Y., Yang, H. J., Sun, W., et al., 2015. A New Laboratory Study on Alternate Injection of High Strength Foam and Ultra-Low Interfacial Tension Foam to Enhance Oil Recovery. Journal of Petroleum Science and Engineering, 125: 75-89. https://doi.org/10.13039/501100001809
    Cui, L. , 2014. Application of Foam for Mobility Control in Enhanced Oil Recovery (EOR) Process: [Dissertation]. Rice University, Huston https: //scholarship. rice. edu/handle/1911/76425
    Du, D. X., Wang, D. X., Jia, N. H., et al., 2016. Experiments on CO2 Foam Seepage Characteristics in Porous Media. Petroleum Exploration and Development, 43(3): 499-505. https://doi.org/10.1016/s1876-3804(16)30058-1
    Ettinger, R. A., Radke, C. J., 1992. Influence of Texture on Steady Foam Flow in Berea Sandstone. SPE Reservoir Engineering, 7(1): 83-90. https://doi.org/10.2118/19688-pa
    Falls, A. H., Musters, J. J., Ratulowski, J., 1989. The Apparent Viscosity of Foams in Homogeneous Bead Packs. SPE Reservoir Engineering, 4(2): 155-164. https://doi.org/10.2118/16048-pa
    Farajzadeh, R., Andrianov, A., Krastev, R., et al., 2012. Foam-Oil Interaction in Porous Media: Implications for Foam Assisted Enhanced Oil Recovery. Advances in Colloid and Interface Science, 183/184: 1-13. https://doi.org/10.1016/j.cis.2012.07.002
    Farajzadeh, R., Lotfollahi, M., Eftekhari, A. A., et al., 2015. Effect of Permeability on Implicit-Texture Foam Model Parameters and the Limiting Capillary Pressure. Energy & Fuels, 29(5): 3011-3018. https://doi.org/10.13039/100004378
    Foroozesh, J., Jamiolahmady, M., 2016. Simulation of Carbonated Water Injection Coreflood Experiments: An Insight into the Wettability Effect. Fuel, 184: 581-589. https://doi.org/10.1016/j.fuel.2016.07.051
    Foroozesh, J., Jamiolahmady, M., Sohrabi, M., 2016. Mathematical Modeling of Carbonated Water Injection for EOR and CO2 Storage with a Focus on Mass Transfer Kinetics. Fuel, 174: 325-332. https://doi.org/10.13039/501100004225
    Foroozesh, J. , Jamiolahmady, M. , Sohrabi, M. , et al. , 2014. Non-equilibrium Based Compositional Simulation of Carbonated Water Injection EOR Technique. In: ECMOR XIV-14th European Conference on the Mathematics of Oil Recovery, Catania, United Kingdom https: //researchportal. hw. ac. uk/en/publications/non-equilibrium-based-compositional-simulation-of-carbonated-wate
    Green, D. W. , Willhite, G. P. , 1998. Enhanced Oil Recovery. Henry L. Doherty Memorial Fund of AIME. Society of Petroleum Engineers, Richardson, TX
    Gu, M., Mohanty, K. K., 2015. Rheology of Polymer-Free Foam Fracturing Fluids. Journal of Petroleum Science and Engineering, 134: 87-96. https://doi.org/10.13039/501100004342
    Herzhaft, B., 1999. Rheology of Aqueous Foams: A Literature Review of some Experimental Works. Oil & Gas Science and Technology, 54(5): 587-596. https://doi.org/10.2516/ogst:1999050
    Jones, S. A., van der Bent, V., Farajzadeh, R., et al., 2016. Surfactant Screening for Foam EOR: Correlation between Bulk and Core-Flood Experiments. Colloids and Surfaces A: Physicochemical and Engineering Aspects, 500: 166-176. https://doi.org/10.1016/j.colsurfa.2016.03.072
    Kapetas, L., Vincent Bonnieu, S., Danelis, S., et al., 2016. Effect of Temperature on Foam Flow in Porous Media. Journal of Industrial and Engineering Chemistry, 36: 229-237. https://doi.org/10.1016/j.jiec.2016.02.001
    Kuuskraa, V. A., Godec, M. L., Dipietro, P., 2013. CO2 Utilization from "Next Generation" CO2 Enhanced Oil Recovery Technology. Energy Procedia, 37: 6854-6866. https://doi.org/10.1016/j.egypro.2013.06.618
    Lee, H. O., Heller, J. P., 1990. Laboratory Measurements of CO2-Foam Mobility. SPE Reservoir Engineering, 5(2): 193-197. https://doi.org/10.2118/17363-pa
    Li, R. F., Yan, W., Liu, S. H., et al., 2010. Foam Mobility Control for Surfactant Enhanced Oil Recovery. SPE Journal, 15(4): 928-942. https://doi.org/10.2118/113910-pa
    Llave, F. , Chung, F. -H. , Louvier, R. , et al. , 1990. Foams as Mobility Control Agents for Oil Recovery by Gas Displacement. In: SPE/DOE Enhanced Oil Recovery Symposium, Society of Petroleum Engineers https: //www. onepetro. org/conference-paper/SPE-20245-MS
    Ma, K. , 2013. Transport of Surfactant and Foam in Porous Media for Enhanced Oil Recovery Processes: [Dissertation]. Rice University, Huston https: //scholarship. rice. edu/handle/1911/71996
    Ma, K., Ren, G. W., Mateen, K., et al., 2015. Modeling Techniques for Foam Flow in Porous Media. SPE Journal, 20(3): 453-470. https://doi.org/10.2118/169104-pa
    Marsden, S. , 1986. Foams in Porous Media. U. S. Department of Energy https: //www. osti. gov/scitech/biblio/5866567
    Nguyen, Q. P. , Alexandrov, A. V. , Zitha, P. L. , et al. , 2000. Experimental and Modeling Studies on Foam in Porous Media: A Review. In: SPE International Symposium on Formation Damage Control, Society of Petroleum Engineers, Lafayette, Louisiana https: //www. onepetro. org/conference-paper/SPE-58799-MS
    Osei-Bonsu, K., Shokri, N., Grassia, P., 2015. Foam Stability in the Presence and Absence of Hydrocarbons: From Bubble-to Bulk-Scale. Colloids and Surfaces A: Physicochemical and Engineering Aspects, 481: 514-526. https://doi.org/10.1016/j.colsurfa.2015.06.023
    Osei-Bonsu, K., Shokri, N., Grassia, P., 2016. Fundamental Investigation of Foam Flow in a Liquid-Filled Hele-Shaw Cell. Journal of Colloid and Interface Science, 462: 288-296. https://doi.org/10.13039/100006770
    Pramudita, R. A., Ryoo, W. S., 2016. Viscosity Measurements of CO2-In-Water Foam with Dodecyl Polypropoxy Sulfate Surfactants for Enhanced Oil Recovery Application. Korea-Australia Rheology Journal, 28(3): 237-241. https://doi.org/10.1007/s13367-016-0024-5
    Qin, J. S., Han, H. S., Liu, X. L., 2015. Application and Enlightenment of Carbon Dioxide Flooding in the United States of America. Petroleum Exploration and Development, 42(2): 232-240. https://doi.org/10.1016/s1876-3804(15)30010-0
    Simjoo, M., Rezaei, T., Andrianov, A., et al., 2013. Foam Stability in the Presence of Oil: Effect of Surfactant Concentration and Oil Type. Colloids and Surfaces A: Physicochemical and Engineering Aspects, 438: 148-158. https://doi.org/10.1016/j.colsurfa.2013.05.062
    Stevenson, P., 2012. Foam Engineering: Fundamentals and Applications. John Wiley & Sons, New Zealand
    Sun, X., Liang, X. B., Wang, S. Z., et al., 2014. Experimental Study on the Rheology of CO2 Viscoelastic Surfactant Foam Fracturing Fluid. Journal of Petroleum Science and Engineering, 119: 104-111. https://doi.org/10.1016/j.petrol.2014.04.017
    Sun, Y. G., Qi, X. Q., Sun, H. Y., et al., 2016. Understanding about how Different Foaming Gases Effect the Interfacial Array Behaviors of Surfactants and the Foam Properties. Langmuir, 32(30): 7503-7511. https://doi.org/10.13039/501100002855
    Vincent-Bonnieu, S. , Jones, S. , 2014. Comparative Study of Foam Stability in Bulk and Porous Media: [Dissertation]. Delft University of Technology, TU Delft https: //repository. tudelft. nl/islandora/object/uuid: 18f25d68-06f4-4a1d-9e93-ed89c1213416?collection=education
    Wang, G. F., Zheng, X. J., Zhang, Y., et al., 2015. A New Screening Method of Low Permeability Reservoirs Suitable for CO2 Flooding. Petroleum Exploration and Development, 42(3): 390-396. https://doi.org/10.1016/s1876-3804(15)30030-6
    Wang, J., Liu, H. Q., Ning, Z. F., et al., 2012. Experimental Research and Quantitative Characterization of Nitrogen Foam Blocking Characteristics. Energy & Fuels, 26(8): 5152-5163. https://doi.org/10.1021/ef300939j
    Xiao, C. , Balasubramanian, S. N. , Clapp, L. W. , 2016. Rheology of Supercritical CO2 Foam Stabilized by Nanoparticles. In: SPE Improved Oil Recovery Conference, Society of Petroleum Engineers, Tulsa, Oklahoma https: //www. onepetro. org/conference-paper/SPE-179621-MS
    Xu, X., Saeedi, A., Liu, K., 2016. Laboratory Studies on CO2 Foam Flooding Enhanced by a Novel Amphiphilic Ter-Polymer. Journal of Petroleum Science and Engineering, 138: 153-159. https://doi.org/10.1016/j.petrol.2015.10.025
    Yan, W., Miller, C. A., Hirasaki, G. J., 2006. Foam Sweep in Fractures for Enhanced Oil Recovery. Colloids and Surfaces A: Physicochemical and Engineering Aspects, 282/283: 348-359. https://doi.org/10.1016/j.colsurfa.2006.02.067
    Zeng, Y. C., Ma, K., Farajzadeh, R., et al., 2016. Effect of Surfactant Partitioning between Gaseous Phase and Aqueous Phase on CO2 Foam Transport for Enhanced Oil Recovery. Transport in Porous Media, 114(3): 777-793. https://doi.org/10.1007/s11242-016-0743-6
    Zhang, Z. , Freedman, V. L. , Zhong, L. , 2009. Foam Transport in Porous Media—A Review. Pacific Northwest National Laboratory, Washington https: //digital. library. unt. edu/ark: /67531/metadc841157/
    Zhou, M., Wang, C. W., Xing, T. T., et al., 2015. Studies on Foam Flooding for Saline Reservoirs after Polymer Flooding. Journal of Petroleum Science and Engineering, 135: 410-420. https://doi.org/10.1016/j.petrol.2015.09.020
    • Relative Articles
    • Supplements(0)
    • Cited By
  • 加载中

Catalog

    通讯作者: 陈斌, bchen63@163.com
    • 1. 

      沈阳化工大学材料科学与工程学院 沈阳 110142

    1. 本站搜索
    2. 百度学术搜索
    3. 万方数据库搜索
    4. CNKI搜索

    Figures(7)

    Get Citation
    PDF
    XML

    Article Metrics

    Article views(2095) PDF downloads(201) Cited by()
    Proportional views
    Related

    Copyright © 2013-2020 Journal of Earth Science 鄂ICP备15021562号-2

    Tel: +86-27-67885075 Fax: +86-27-67885075 E-mail: xbb@cug.edu.cn

    Address: Editorial Office of Journal, China University of Geosciences, Yujiashan, Wuhan, Hubei 430074, P. R. China

    Supported by: Beijing Renhe Information Technology Co. Ltd  E-mail: info@rhhz.net  

    /

    DownLoad:  Full-Size Img  PowerPoint
    Return
    Return