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Heterogeneity of a Sandy Conglomerate Reservoir in Qie12 Block, Qaidam Basin, Northwest China and Its Influence on Remaining Oil Distribution

Author

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  • Qingshun Gong

    (PetroChina Hangzhou Research Institute of Geology, Hangzhou 310023, China)

  • Zhanguo Liu

    (PetroChina Hangzhou Research Institute of Geology, Hangzhou 310023, China)

  • Chao Zhu

    (PetroChina Hangzhou Research Institute of Geology, Hangzhou 310023, China)

  • Bo Wang

    (Exploration and Development Institute of Qinghai Oilfield Company, CNPC, Dunhuang 736202, China)

  • Yijie Jin

    (China National Logging Company, Beijing 100101, China)

  • Zhenghao Shi

    (Exploration and Development Institute of Qinghai Oilfield Company, CNPC, Dunhuang 736202, China)

  • Lin Xie

    (Exploration and Development Institute of Qinghai Oilfield Company, CNPC, Dunhuang 736202, China)

  • Jin Wu

    (PetroChina Hangzhou Research Institute of Geology, Hangzhou 310023, China)

Abstract

In view of the key geological factors restricting reservoir development, the reservoir heterogeneity of an alluvial fan sandy conglomerate reservoir in the Qie12 block of Qaidam Basin, Northwest China, and its influence on remaining oil distribution, were studied according to geology, wireline logging data, and dynamic production data. This study illustrates that the difference in pore structures, which are controlled by different sedimentary fabrics, is the main cause of reservoir microscopic heterogeneity. Besides, the temporal and spatial distribution of architectural units in the alluvial fan controls reservoir macroheterogeneity. Our results show that the thick sandy conglomerate develops two types of pores, two types of permeability rhythms, two types of interlayers, two types of interlayer distribution, two types of effective sand body architecture, and four types of sand body connecting schemes. The strongest plane heterogeneity is found in the composite channel unit formed by overlapping and separated stable channels of the middle fan, and the unit’s permeability variation coefficient is >0.7. However, the variation coefficient in the range of 0.3–0.5 is found in the extensively connected body unit sandwiched with intermittent channels of the inner fan. The distributions of the remaining oil vary significantly in different architectural units because of the influence of reservoir heterogeneity, including distribution patterns of flow barriers, permeability rhythm, and reservoir pore structures. The composite channel unit formed by overlapping and separated stable channels, or the lateral alternated unit with braided channel and sheet flow sediment of the middle fan, is influenced by the inhomogeneous breakthrough of injection water flowing along the dominant channel in a high-permeability layer. The microscopic surrounding flow and island-shaped remaining oils form and concentrate mainly in the upper part of a compound rhythmic layer. Meanwhile, in the extensively connected body unit sandwiched with intermittent channels of the inner fan, poor injector–producer connectivity and low reservoir permeability lead to a flake-like enrichment of the remaining oil.

Suggested Citation

  • Qingshun Gong & Zhanguo Liu & Chao Zhu & Bo Wang & Yijie Jin & Zhenghao Shi & Lin Xie & Jin Wu, 2023. "Heterogeneity of a Sandy Conglomerate Reservoir in Qie12 Block, Qaidam Basin, Northwest China and Its Influence on Remaining Oil Distribution," Energies, MDPI, vol. 16(7), pages 1-19, March.
    • Handle: RePEc:gam:jeners:v:16:y:2023:i:7:p:2972-:d:1106486
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    References listed on IDEAS

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    1. Danial Kaviani & Peter Valkó & Jerry Jensen, 2011. "Analysis of Injection and Production Data for Open and Large Reservoirs," Energies, MDPI, vol. 4(11), pages 1-23, November.
    2. Irena Viktorovna Yazynina & Evgeny Vladimirovich Shelyago & Andrey Andreevich Abrosimov & Vladimir Stanislavovich Yakushev, 2021. "New Method of Oil Reservoir Rock Heterogeneity Quantitative Estimation from X-ray MCT Data," Energies, MDPI, vol. 14(16), pages 1-8, August.
    3. Penghui Su & Zhaohui Xia & Ping Wang & Wei Ding & Yunpeng Hu & Wenqi Zhang & Yujie Peng, 2019. "Fractal and Multifractal Analysis of Pore Size Distribution in Low Permeability Reservoirs Based on Mercury Intrusion Porosimetry," Energies, MDPI, vol. 12(7), pages 1-15, April.
    4. Ridha Gharbi & Abdullah Alajmi & Meshal Algharaib, 2012. "The Potential of a Surfactant/Polymer Flood in a Middle Eastern Reservoir," Energies, MDPI, vol. 5(1), pages 1-13, January.
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