IDEAS home Printed from https://ideas.repec.org/a/gam/jeners/v11y2018i4p702-d137306.html
   My bibliography  Save this article

Experimental Study of Matrix Permeability of Gas Shale: An Application to CO 2 -Based Shale Fracturing

Author

Listed:
  • Chengpeng Zhang

    (Deep Earth Energy Laboratory, Department of Civil Engineering, Monash University, Building 60, Melbourne, VIC 3800, Australia)

  • Pathegama Gamage Ranjith

    (Deep Earth Energy Laboratory, Department of Civil Engineering, Monash University, Building 60, Melbourne, VIC 3800, Australia)

Abstract

Because the limitations of water-based fracturing fluids restrict their fracturing efficiency and scope of application, liquid CO 2 is regarded as a promising substitute, owing to its unique characteristics, including its greater environmental friendliness, shorter clean-up time, greater adsorption capacity than CH 4 and less formation damage. Conversely, the disadvantage of high leak-off rate of CO 2 fracturing due to its very low viscosity determines its applicability in gas shales with ultra-low permeability, accurate measurement of shale permeability to CO 2 is therefore crucial to evaluate the appropriate injection rate and total consumption of CO 2 . The main purpose of this study is to accurately measure shale permeability to CO 2 flow during hydraulic fracturing, and to compare the leak-off of CO 2 and water fracturing. A series of permeability tests was conducted on cylindrical shale samples 38 mm in diameter and 19 mm long using water, CO 2 in different phases and N 2 considering multiple influencing factors. According to the experimental results, the apparent permeability of shale matrix to gaseous CO 2 or N 2 is greatly over-estimated compared with intrinsic permeability or that of liquid CO 2 due to the Klinkenberg effect. This phenomenon explains that the permeability values measured under steady-state conditions are much higher than those under transient conditions. Supercritical CO 2 with higher molecular kinetic energy has slightly higher permeability than liquid CO 2 . The leak-off rate of CO 2 is an order of magnitude higher than that of water under the same injection conditions due to its lower viscosity. The significant decrease of shale permeability to gas after water flooding is due to the water block effect, and much longer clean-up time and deep water imbibition depth greatly impede the gas transport from the shale matrix to the created fractures. Therefore, it is necessary to substitute water-based fracturing fluids with liquid or super-critical CO 2 in clay-abundant shale formations.

Suggested Citation

  • Chengpeng Zhang & Pathegama Gamage Ranjith, 2018. "Experimental Study of Matrix Permeability of Gas Shale: An Application to CO 2 -Based Shale Fracturing," Energies, MDPI, vol. 11(4), pages 1-17, March.
    • Handle: RePEc:gam:jeners:v:11:y:2018:i:4:p:702-:d:137306
    as

    Download full text from publisher

    File URL: https://www.mdpi.com/1996-1073/11/4/702/pdf
    Download Restriction: no
    File URL: https://www.mdpi.com/1996-1073/11/4/702/
    Download Restriction: no
    ---><---

    References listed on IDEAS

    as
    1. Leung, Dennis Y.C. & Caramanna, Giorgio & Maroto-Valer, M. Mercedes, 2014. "An overview of current status of carbon dioxide capture and storage technologies," Renewable and Sustainable Energy Reviews, Elsevier, vol. 39(C), pages 426-443.
    2. De Silva, G.P.D. & Ranjith, P.G. & Perera, M.S.A. & Chen, B., 2016. "Effect of bedding planes, their orientation and clay depositions on effective re-injection of produced brine into clay rich deep sandstone formations: Implications for deep earth energy extraction," Applied Energy, Elsevier, vol. 161(C), pages 24-40.
    3. Middleton, Richard S. & Carey, J. William & Currier, Robert P. & Hyman, Jeffrey D. & Kang, Qinjun & Karra, Satish & Jiménez-Martínez, Joaquín & Porter, Mark L. & Viswanathan, Hari S., 2015. "Shale gas and non-aqueous fracturing fluids: Opportunities and challenges for supercritical CO2," Applied Energy, Elsevier, vol. 147(C), pages 500-509.
    Full references (including those not matched with items on IDEAS)

    Citations

    Citations are extracted by the CitEc Project, subscribe to its RSS feed for this item.
    as


    Cited by:

    1. Muhammad Shahzad Kamal & Marwan Mohammed & Mohamed Mahmoud & Salaheldin Elkatatny, 2018. "Development of Chelating Agent-Based Polymeric Gel System for Hydraulic Fracturing," Energies, MDPI, vol. 11(7), pages 1-15, June.
    2. Xiangxiang Zhang & Jianguo Wang & Feng Gao & Xiaolin Wang, 2018. "Numerical Study of Fracture Network Evolution during Nitrogen Fracturing Processes in Shale Reservoirs," Energies, MDPI, vol. 11(10), pages 1-22, September.
    3. Arash Kamali-Asl & Mark D Zoback & Arjun H. Kohli, 2021. "Effects of Supercritical CO 2 on Matrix Permeability of Unconventional Formations," Energies, MDPI, vol. 14(4), pages 1-29, February.

    Most related items

    These are the items that most often cite the same works as this one and are cited by the same works as this one.
    1. Costa, Isabella & Rochedo, Pedro & Costa, Daniele & Ferreira, Paula & Araújo, Madalena & Schaeffer, Roberto & Szklo, Alexandre, 2019. "Placing hubs in CO2 pipelines: An application to industrial CO2 emissions in the Iberian Peninsula," Applied Energy, Elsevier, vol. 236(C), pages 22-31.
    2. Hou, Lei & Elsworth, Derek & Wang, Jintang & Zhou, Junping & Zhang, Fengshou, 2024. "Feasibility and prospects of symbiotic storage of CO2 and H2 in shale reservoirs," Renewable and Sustainable Energy Reviews, Elsevier, vol. 189(PA).
    3. Yin, Hong & Zhou, Junping & Xian, Xuefu & Jiang, Yongdong & Lu, Zhaohui & Tan, Jingqiang & Liu, Guojun, 2017. "Experimental study of the effects of sub- and super-critical CO2 saturation on the mechanical characteristics of organic-rich shales," Energy, Elsevier, vol. 132(C), pages 84-95.
    4. Filip Simeski & Matthias Ihme, 2023. "Supercritical fluids behave as complex networks," Nature Communications, Nature, vol. 14(1), pages 1-10, December.
    5. Weiqiang Song & Hongjian Ni & Ruihe Wang & Mengyun Zhao, 2017. "Wellbore flow field of coiled tubing drilling with supercritical carbon dioxide," Greenhouse Gases: Science and Technology, Blackwell Publishing, vol. 7(4), pages 745-755, August.
    6. Liang, Ying & Cai, Lei & Guan, Yanwen & Liu, Wenbin & Xiang, Yanlei & Li, Juan & He, Tianzhi, 2020. "Numerical study on an original oxy-fuel combustion power plant with efficient utilization of flue gas waste heat," Energy, Elsevier, vol. 193(C).
    7. Zhao‐Zhong Yang & Liang‐Ping Yi & Xiao‐Gang Li & Yu Li & Min Jia, 2018. "Phase control of downhole fluid during supercritical carbon dioxide fracturing," Greenhouse Gases: Science and Technology, Blackwell Publishing, vol. 8(6), pages 1079-1089, December.
    8. Gintautas Mozgeris & Daiva Juknelienė, 2021. "Modeling Future Land Use Development: A Lithuanian Case," Land, MDPI, vol. 10(4), pages 1-21, April.
    9. Balcombe, Paul & Speirs, Jamie & Johnson, Erin & Martin, Jeanne & Brandon, Nigel & Hawkes, Adam, 2018. "The carbon credentials of hydrogen gas networks and supply chains," Renewable and Sustainable Energy Reviews, Elsevier, vol. 91(C), pages 1077-1088.
    10. Attahiru, Yusuf Babangida & Aziz, Md. Maniruzzaman A. & Kassim, Khairul Anuar & Shahid, Shamsuddin & Wan Abu Bakar, Wan Azelee & NSashruddin, Thanwa Filza & Rahman, Farahiyah Abdul & Ahamed, Mohd Imra, 2019. "A review on green economy and development of green roads and highways using carbon neutral materials," Renewable and Sustainable Energy Reviews, Elsevier, vol. 101(C), pages 600-613.
    11. Pellegrino, Sandro & Lanzini, Andrea & Leone, Pierluigi, 2017. "Greening the gas network – The need for modelling the distributed injection of alternative fuels," Renewable and Sustainable Energy Reviews, Elsevier, vol. 70(C), pages 266-286.
    12. Christian Breyer & Mahdi Fasihi & Arman Aghahosseini, 2020. "Carbon dioxide direct air capture for effective climate change mitigation based on renewable electricity: a new type of energy system sector coupling," Mitigation and Adaptation Strategies for Global Change, Springer, vol. 25(1), pages 43-65, January.
    13. Huang, Liang & Ning, Zhengfu & Wang, Qing & Zhang, Wentong & Cheng, Zhilin & Wu, Xiaojun & Qin, Huibo, 2018. "Effect of organic type and moisture on CO2/CH4 competitive adsorption in kerogen with implications for CO2 sequestration and enhanced CH4 recovery," Applied Energy, Elsevier, vol. 210(C), pages 28-43.
    14. Zhang, Hanfei & Wang, Ligang & Pérez-Fortes, Mar & Van herle, Jan & Maréchal, François & Desideri, Umberto, 2020. "Techno-economic optimization of biomass-to-methanol with solid-oxide electrolyzer," Applied Energy, Elsevier, vol. 258(C).
    15. Khan, Muhammad Usman & Lee, Jonathan Tian En & Bashir, Muhammad Aamir & Dissanayake, Pavani Dulanja & Ok, Yong Sik & Tong, Yen Wah & Shariati, Mohammad Ali & Wu, Sarah & Ahring, Birgitte Kiaer, 2021. "Current status of biogas upgrading for direct biomethane use: A review," Renewable and Sustainable Energy Reviews, Elsevier, vol. 149(C).
    16. Nguyen, Phong & Carey, J. William & Viswanathan, Hari S. & Porter, Mark, 2018. "Effectiveness of supercritical-CO2 and N2 huff-and-puff methods of enhanced oil recovery in shale fracture networks using microfluidic experiments," Applied Energy, Elsevier, vol. 230(C), pages 160-174.
    17. Drissi, Sarra & Ling, Tung-Chai & Mo, Kim Hung & Eddhahak, Anissa, 2019. "A review of microencapsulated and composite phase change materials: Alteration of strength and thermal properties of cement-based materials," Renewable and Sustainable Energy Reviews, Elsevier, vol. 110(C), pages 467-484.
    18. Anita Punia, 2021. "Carbon dioxide sequestration by mines: implications for climate change," Climatic Change, Springer, vol. 165(1), pages 1-17, March.
    19. Han, Jinju & Lee, Minkyu & Lee, Wonsuk & Lee, Youngsoo & Sung, Wonmo, 2016. "Effect of gravity segregation on CO2 sequestration and oil production during CO2 flooding," Applied Energy, Elsevier, vol. 161(C), pages 85-91.
    20. Zhang, Xiaoyue & Huang, Guohe & Liu, Lirong & Li, Kailong, 2022. "Development of a stochastic multistage lifecycle programming model for electric power system planning – A case study for the Province of Saskatchewan, Canada," Renewable and Sustainable Energy Reviews, Elsevier, vol. 158(C).

    Corrections

    All material on this site has been provided by the respective publishers and authors. You can help correct errors and omissions. When requesting a correction, please mention this item's handle: RePEc:gam:jeners:v:11:y:2018:i:4:p:702-:d:137306. See general information about how to correct material in RePEc.

    If you have authored this item and are not yet registered with RePEc, we encourage you to do it here. This allows to link your profile to this item. It also allows you to accept potential citations to this item that we are uncertain about.

    If CitEc recognized a bibliographic reference but did not link an item in RePEc to it, you can help with this form .

    If you know of missing items citing this one, you can help us creating those links by adding the relevant references in the same way as above, for each refering item. If you are a registered author of this item, you may also want to check the "citations" tab in your RePEc Author Service profile, as there may be some citations waiting for confirmation.

    For technical questions regarding this item, or to correct its authors, title, abstract, bibliographic or download information, contact: MDPI Indexing Manager (email available below). General contact details of provider: https://www.mdpi.com .

    Please note that corrections may take a couple of weeks to filter through the various RePEc services.

    IDEAS is a RePEc service. RePEc uses bibliographic data supplied by the respective publishers.