IDEAS home Printed from https://ideas.repec.org/a/gam/jeners/v11y2018i7p1663-d154524.html
   My bibliography  Save this article

Development of Chelating Agent-Based Polymeric Gel System for Hydraulic Fracturing

Author

Listed:
  • Muhammad Shahzad Kamal

    (Center for Integrative Petroleum Research, King Fahd University of Petroleum & Minerals, Dhahran 31261, Saudi Arabia)

  • Marwan Mohammed

    (Department of Petroleum Engineering, King Fahd University of Petroleum & Minerals, Dhahran 31261, Saudi Arabia)

  • Mohamed Mahmoud

    (Department of Petroleum Engineering, King Fahd University of Petroleum & Minerals, Dhahran 31261, Saudi Arabia)

  • Salaheldin Elkatatny

    (Department of Petroleum Engineering, King Fahd University of Petroleum & Minerals, Dhahran 31261, Saudi Arabia)

Abstract

Hydraulic Fracturing is considered to be one of the most important stimulation methods. Hydraulic Fracturing is carried out by inducing fractures in the formation to create conductive pathways for the flow of hydrocarbon. The pathways are kept open either by using proppant or by etching the fracture surface using acids. A typical fracturing fluid usually consists of a gelling agent (polymers), cross-linkers, buffers, clay stabilizers, gel stabilizers, biocide, surfactants, and breakers mixed with fresh water. The numerous additives are used to prevent damage resulting from such operations, or better yet, enhancing it beyond just the aim of a fracturing operation. This study introduces a new smart fracturing fluid system that can be either used for proppant fracturing (high pH) or acid fracturing (low pH) operations in sandstone formations. The fluid system consists of glutamic acid diacetic acid (GLDA) that can replace several additives, such as cross-linker, breaker, biocide, and clay stabilizer. GLDA is also a surface-active fluid that will reduce the interfacial tension eliminating the water-blockage effect. GLDA is compatible and stable with sea water, which is advantageous over the typical fracturing fluid. It is also stable in high temperature reservoirs (up to 300 °F) and it is also environmentally friendly and readily biodegradable. The new fracturing fluid formulation can withstand up to 300 °F of formation temperature and is stable for about 6 h under high shearing rates (511 s −1 ). The new fracturing fluid formulation breaks on its own and the delay time or the breaking time can be controlled with the concentrations of the constituents of the fluid (GLDA or polymer). Coreflooding experiments were conducted using Scioto and Berea sandstone cores to evaluate the effectiveness of the developed fluid. The flooding experiments were in reasonable conformance with the rheological properties of the developed fluid regarding the thickening and breaking time, as well as yielding high return permeability.

Suggested Citation

  • 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.
  • Handle: RePEc:gam:jeners:v:11:y:2018:i:7:p:1663-:d:154524
    as

    Download full text from publisher

    File URL: https://www.mdpi.com/1996-1073/11/7/1663/pdf
    Download Restriction: no

    File URL: https://www.mdpi.com/1996-1073/11/7/1663/
    Download Restriction: no
    ---><---

    References listed on IDEAS

    as
    1. Hadi Parvizi & Sina Rezaei Gomari & Farhad Nabhani & Abolfazl Dehghan Monfared, 2018. "Modeling the Risk of Commercial Failure for Hydraulic Fracturing Projects Due to Reservoir Heterogeneity," Energies, MDPI, vol. 11(1), pages 1-14, January.
    2. Jianming He & Lekan Olatayo Afolagboye & Chong Lin & Xiaole Wan, 2018. "An Experimental Investigation of Hydraulic Fracturing in Shale Considering Anisotropy and Using Freshwater and Supercritical CO 2," Energies, MDPI, vol. 11(3), pages 1-13, March.
    3. Shehzad Ahmed & Khaled Abdalla Elraies & Muhammad Rehan Hashmet & Mohamad Sahban Alnarabiji, 2018. "Empirical Modeling of the Viscosity of Supercritical Carbon Dioxide Foam Fracturing Fluid under Different Downhole Conditions," Energies, MDPI, vol. 11(4), pages 1-16, March.
    4. Mingtao Fan & Jun Li & Gonghui Liu, 2018. "New Method to Analyse the Cement Sheath Integrity During the Volume Fracturing of Shale Gas," Energies, MDPI, vol. 11(4), pages 1-16, March.
    5. Shehzad Ahmed & Khaled Abdalla Elraies & Muhammad Rehan Hashmet & Alvinda Sri Hanamertani, 2017. "Viscosity Models for Polymer Free CO 2 Foam Fracturing Fluid with the Effect of Surfactant Concentration, Salinity and Shear Rate," Energies, MDPI, vol. 10(12), pages 1-12, November.
    6. 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.
    7. Fei Wang & Baoman Li & Yichi Zhang & Shicheng Zhang, 2017. "Coupled Thermo-Hydro-Mechanical-Chemical Modeling of Water Leak-Off Process during Hydraulic Fracturing in Shale Gas Reservoirs," Energies, MDPI, vol. 10(12), pages 1-17, November.
    8. 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. Jianchao Cai & Zhien Zhang & Qinjun Kang & Harpreet Singh, 2019. "Recent Advances in Flow and Transport Properties of Unconventional Reservoirs," Energies, MDPI, vol. 12(10), pages 1-5, May.
    2. Erdong Yao & Hang Xu & Yuan Li & Xuesong Ren & Hao Bai & Fujian Zhou, 2021. "Reusing Flowback and Produced Water with Different Salinity to Prepare Guar Fracturing Fluid," Energies, MDPI, vol. 15(1), pages 1-18, December.

    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. 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.
    2. Shehzad Ahmed & Khaled Abdalla Elraies & Muhammad Rehan Hashmet & Mohamad Sahban Alnarabiji, 2018. "Empirical Modeling of the Viscosity of Supercritical Carbon Dioxide Foam Fracturing Fluid under Different Downhole Conditions," Energies, MDPI, vol. 11(4), pages 1-16, March.
    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.
    4. Muhammad Shahzad Kamal, 2019. "A Novel Approach to Stabilize Foam Using Fluorinated Surfactants," Energies, MDPI, vol. 12(6), pages 1-12, March.
    5. 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.
    6. Filip Simeski & Matthias Ihme, 2023. "Supercritical fluids behave as complex networks," Nature Communications, Nature, vol. 14(1), pages 1-10, December.
    7. 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.
    8. 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.
    9. Przemyslaw Michal Wilczynski & Andrzej Domonik & Pawel Lukaszewski, 2021. "Anisotropy of Strength and Elastic Properties of Lower Paleozoic Shales from the Baltic Basin, Poland," Energies, MDPI, vol. 14(11), pages 1-17, May.
    10. 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.
    11. 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.
    12. Zhang, Shuo & Song, Shengyuan & Zhang, Wen & Zhao, Jinmin & Cao, Dongfang & Ma, Wenliang & Chen, Zijian & Hu, Ying, 2023. "Research on the inherent mechanism of rock mass deformation of oil shale in-situ mining under the condition of thermal-fluid-solid coupling," Energy, Elsevier, vol. 280(C).
    13. 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.
    14. An, Qiyi & Zhang, Qingsong & Li, Xianghui & Yu, Hao & Yin, Zhanchao & Zhang, Xiao, 2022. "Accounting for dynamic alteration effect of SC-CO2 to assess role of pore structure on rock strength: A comparative study," Energy, Elsevier, vol. 260(C).
    15. Yuqiang Xu & Yan Yan & Shenqi Xu & Zhichuan Guan, 2020. "Numerical Simulation Study on Propagation of Initial Microcracks in Cement Sheath Body during Hydraulic Fracturing Process," Energies, MDPI, vol. 13(5), pages 1-18, March.
    16. Zhou, Junping & Tian, Shifeng & Zhou, Lei & Xian, Xuefu & Yang, Kang & Jiang, Yongdong & Zhang, Chengpeng & Guo, Yaowen, 2020. "Experimental investigation on the influence of sub- and super-critical CO2 saturation time on the permeability of fractured shale," Energy, Elsevier, vol. 191(C).
    17. Tong, Zi-Xiang & Li, Ming-Jia & He, Ya-Ling & Tan, Hou-Zhang, 2017. "Simulation of real time particle deposition and removal processes on tubes by coupled numerical method," Applied Energy, Elsevier, vol. 185(P2), pages 2181-2193.
    18. Pan, Jienan & Du, Xuetian & Wang, Xianglong & Hou, Quanlin & Wang, Zhenzhi & Yi, Jiale & Li, Meng, 2024. "Pore and permeability changes in coal induced by true triaxial supercritical carbon dioxide fracturing based on low-field nuclear magnetic resonance," Energy, Elsevier, vol. 286(C).
    19. Hanamertani, Alvinda Sri & Ahmed, Shehzad, 2021. "Probing the role of associative polymer on scCO2-Foam strength and rheology enhancement in bulk and porous media for improving oil displacement efficiency," Energy, Elsevier, vol. 228(C).
    20. Li, Bo & Yu, Hao & Xu, WenLong & Huang, HanWei & Huang, MengCheng & Meng, SiWei & Liu, He & Wu, HengAn, 2023. "A multi-physics coupled multi-scale transport model for CO2 sequestration and enhanced recovery in shale formation with fractal fracture networks," Energy, Elsevier, vol. 284(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:7:p:1663-:d:154524. 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.