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Petrographic characterization to build an accurate rock model using micro-CT: Case study on low-permeable to tight turbidite sandstone from Eocene Shahejie Formation

(2018) MICRON. 109. p.22-33
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Abstract
Pore scale flow simulations heavily depend on petrographic characterizing and modeling of reservoir rocks. Mineral phase segmentation and pore network modeling are crucial stages in micro-CT based rock modeling. The success of the pore network model (PNM) to predict petrophysical properties relies on image segmentation, image resolution and most importantly nature of rock (homogenous, complex or microporous). The pore network modeling has experienced extensive research and development during last decade, however the application of these models to a variety of naturally heterogenous reservoir rock is still a challenge. In this paper, four samples from a low permeable to tight sandstone reservoir were used to characterize their petrographic and petrophysical properties using high-resolution micro-CT imaging. The phase segmentation analysis from micro-CT images shows that 5-6% microporous regions are present in kaolinite rich sandstone (E3 and E4), while 1.7-1.8% are present in illite rich sandstone (El and E2). The pore system percolates without micropores in El and E2 while it does not percolate without micropores in E3 and E4. In El and E2, total MICP porosity is equal to the volume percent of macrospores determined from micro-CT images, which indicate that the macropores are well connected and microspores do not play any role in non-wetting fluid (mercury) displacement process. Whereas in E3 and E4 sandstones, the volume percent of micropores is far less (almost 50%) than the total MICP porosity which means that almost half of the pore space was not detected by the micro-CT scan. PNM behaved well in El and E2 where better agreement exists in PNM and MICP measurements. While E3 and E4 exhibit multiscale pore space which cannot be addressed with single scale PNM method, a multiscale approach is needed to characterize such complex rocks. This study provides helpful insights towards the application of existing micro-CT based petrographic characterization methodology to naturally complex petroleum reservoir rocks.
Keywords
PORE-NETWORK MODELS, BOHAI BAY BASIN, PETROPHYSICAL PROPERTIES, LACUSTRINE TURBIDITES, TRANSPORT-PROPERTIES, 2-PHASE FLOW, MICROPOROSITY, MULTISCALE, CHINA, MICROTOMOGRAPHY, Pore network model (PNM), Macropores, Micropores, Micro-CT, Tight, sandstone

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Citation

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Chicago
Munawar, Muhammad Jawad, Chengyan Lin, Veerle Cnudde, Tom Bultreys, Chunmei Dong, Xianguo Zhang, Wesley De Boever, Muhammad Aleem Zahid, and Yuqi Wu. 2018. “Petrographic Characterization to Build an Accurate Rock Model Using micro-CT: Case Study on Low-permeable to Tight Turbidite Sandstone from Eocene Shahejie Formation.” Micron 109: 22–33.
APA
Munawar, M. J., Lin, C., Cnudde, V., Bultreys, T., Dong, C., Zhang, X., De Boever, W., et al. (2018). Petrographic characterization to build an accurate rock model using micro-CT: Case study on low-permeable to tight turbidite sandstone from Eocene Shahejie Formation. MICRON, 109, 22–33.
Vancouver
1.
Munawar MJ, Lin C, Cnudde V, Bultreys T, Dong C, Zhang X, et al. Petrographic characterization to build an accurate rock model using micro-CT: Case study on low-permeable to tight turbidite sandstone from Eocene Shahejie Formation. MICRON. Oxford: Pergamon-elsevier Science Ltd; 2018;109:22–33.
MLA
Munawar, Muhammad Jawad, Chengyan Lin, Veerle Cnudde, et al. “Petrographic Characterization to Build an Accurate Rock Model Using micro-CT: Case Study on Low-permeable to Tight Turbidite Sandstone from Eocene Shahejie Formation.” MICRON 109 (2018): 22–33. Print.
@article{8565953,
  abstract     = {Pore scale flow simulations heavily depend on petrographic characterizing and modeling of reservoir rocks. Mineral phase segmentation and pore network modeling are crucial stages in micro-CT based rock modeling. The success of the pore network model (PNM) to predict petrophysical properties relies on image segmentation, image resolution and most importantly nature of rock (homogenous, complex or microporous). The pore network modeling has experienced extensive research and development during last decade, however the application of these models to a variety of naturally heterogenous reservoir rock is still a challenge. In this paper, four samples from a low permeable to tight sandstone reservoir were used to characterize their petrographic and petrophysical properties using high-resolution micro-CT imaging. The phase segmentation analysis from micro-CT images shows that 5-6\% microporous regions are present in kaolinite rich sandstone (E3 and E4), while 1.7-1.8\% are present in illite rich sandstone (El and E2). The pore system percolates without micropores in El and E2 while it does not percolate without micropores in E3 and E4. In El and E2, total MICP porosity is equal to the volume percent of macrospores determined from micro-CT images, which indicate that the macropores are well connected and microspores do not play any role in non-wetting fluid (mercury) displacement process. Whereas in E3 and E4 sandstones, the volume percent of micropores is far less (almost 50\%) than the total MICP porosity which means that almost half of the pore space was not detected by the micro-CT scan. PNM behaved well in El and E2 where better agreement exists in PNM and MICP measurements. While E3 and E4 exhibit multiscale pore space which cannot be addressed with single scale PNM method, a multiscale approach is needed to characterize such complex rocks. This study provides helpful insights towards the application of existing micro-CT based petrographic characterization methodology to naturally complex petroleum reservoir rocks.},
  author       = {Munawar, Muhammad Jawad and Lin, Chengyan and Cnudde, Veerle and Bultreys, Tom and Dong, Chunmei and Zhang, Xianguo and De Boever, Wesley and Zahid, Muhammad Aleem and Wu, Yuqi},
  issn         = {0968-4328},
  journal      = {MICRON},
  language     = {eng},
  pages        = {22--33},
  publisher    = {Pergamon-elsevier Science Ltd},
  title        = {Petrographic characterization to build an accurate rock model using micro-CT: Case study on low-permeable to tight turbidite sandstone from Eocene Shahejie Formation},
  url          = {http://dx.doi.org/10.1016/j.micron.2018.02.010},
  volume       = {109},
  year         = {2018},
}

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