Article: Relative permeability prediction considering complex pore geometry and wetting characteristics in carbonate reservoirs Journal: International Journal of Oil, Gas and Coal Technology (IJOGCT) 2017 Vol.15 No.4 pp.331 - 346 Abstract: The measurement of relative permeability in carbonate rocks is very uncertain because of the complex pore system. Several equations for the relative permeability have been previously developed. However, most equations assume a single pore system that cannot be applied accurately. This study presents a relative permeability estimation method that considers capillary pressure, contact angle, pore size distribution, and residual oil saturation with respect to the heterogeneous pore network. As results, the capillary pressure was observed to have different tendencies for macropore and micropore. Also, the pore size distribution index of the macropore system was greater than the micropore system. For the macropore, water has a higher relative permeability than oil; a small reduction in oil saturation can easily flow water. In contrast, the micropore tends to follow the conventional relative permeability curve. Therefore, stable water displacement was not assured, leading to an early breakthrough for the heterogeneous carbonate rocks. [Received: July 11, 2016; Accepted: January 2, 2017] Inderscience Publishers - linking academia, business and industry through research

Title: Relative permeability prediction considering complex pore geometry and wetting characteristics in carbonate reservoirs

Authors: Sunlee Han; Daewoong Kwak; Youngsoo Lee; Youngho Jang; Wonmo Sung

Addresses: Department of Mineral Resources and Energy Engineering, Chonbuk National University, 567 Baekje-daero, Deokjin-Gu, Jeonju-si, Jeollabuk-do 561-756, South Korea ' Department of Mineral Resources and Energy Engineering, Chonbuk National University, 567 Baekje-daero, Deokjin-Gu, Jeonju-si, Jeollabuk-do 561-756, South Korea ' Department of Mineral Resources and Energy Engineering, Chonbuk National University, 567 Baekje-daero, Deokjin-Gu, Jeonju-si, Jeollabuk-do 561-756, South Korea ' Petroleum and Marine Research Division, Korea Institute of Geoscience and Mineral Resources, 124 Gwahak-ro, Yuseong-gu, Daejeon 34132, Korea ' Department of Natural Resources and Environmental Engineering, Hanyang University, 222 Wangsimni-ro, Seongdong-gu, Seoul 133-791, South Korea

Abstract: The measurement of relative permeability in carbonate rocks is very uncertain because of the complex pore system. Several equations for the relative permeability have been previously developed. However, most equations assume a single pore system that cannot be applied accurately. This study presents a relative permeability estimation method that considers capillary pressure, contact angle, pore size distribution, and residual oil saturation with respect to the heterogeneous pore network. As results, the capillary pressure was observed to have different tendencies for macropore and micropore. Also, the pore size distribution index of the macropore system was greater than the micropore system. For the macropore, water has a higher relative permeability than oil; a small reduction in oil saturation can easily flow water. In contrast, the micropore tends to follow the conventional relative permeability curve. Therefore, stable water displacement was not assured, leading to an early breakthrough for the heterogeneous carbonate rocks. [Received: July 11, 2016; Accepted: January 2, 2017]

Keywords: heterogeneous carbonate reservoir; relative permeability; pore system; capillary pressure; Brooks-Corey equation; two-phase flow.

DOI: 10.1504/IJOGCT.2017.084836

International Journal of Oil, Gas and Coal Technology, 2017 Vol.15 No.4, pp.331 - 346

Received: 30 Jul 2016
Accepted: 30 Dec 2016
Published online: 30 Jun 2017 *

Title: Relative permeability prediction considering complex pore geometry and wetting characteristics in carbonate reservoirs

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