Abstract
AbstractCementation factor has a crucial role in evaluating volumetric reserves for heterogeneous clastic reservoir. Bioturbation is a prominent source of heterogeneity existing in hydrocarbon-bearing formation across the world. The effect of bioturbation on the petrophysical properties of the clastic has not been comprehensively understood yet, especially its effect on cementation factor estimation. The precise description of such properties is beneficial in developing better volumetric estimates and optimizing field development planning. The present work discusses an approach to characterize cementation factor in bioturbated clastic Bhuj Formation, Kachchh Basin, India. In order to ascertain the cementation exponent for bioturbated media, an improved triple-porosity model is proposed by quantifying the total porous volume into three components, namely matrix 1, matrix 2 and bioturbated region. An equivalent resistance model is then developed by identifying the series and parallel relation between the two matrix components and the burrow. The experimental observations of electrical response indicated large variation in resistivity in vertical cores compared to horizontal cores. The decreased resistivity is due to the vertically aligned burrow which due to their enhanced porosity provides less tortuous path for current to flow. The triple-porosity model is validated with different porosity value of matrix 1, matrix 2 and burrow, and a cementation factor of 2.8 for higher bioturbated samples and 3 for lower bioturbated samples is obtained. This validates the previous understanding of enhanced flow and storage property and thereby produces a consistent way to evaluate total cementation factor. The correct estimation of cementation factor helps in precise evaluation of water saturation in bioturbated reservoirs.
Publisher
Springer Science and Business Media LLC
Subject
General Energy,Geotechnical Engineering and Engineering Geology
Reference40 articles.
1. Aguilera RF (1976) Analysis of natural fractured reservoirs from conventional well logs. J Petrol Technol 28(7):764–772. https://doi.org/10.2118/5342-PA
2. Aguilera RF (2010) Effect of fracture dip and fracture tortuosity on petrophysical evaluation of naturally fractured reservoir. J Can Pet Technol 49(9):69–76. https://doi.org/10.2118/139847-PA
3. Aguilera RF, Aguilera MS (2003) Improved model for petrophysical analysis of dual-porosity reservoir. Petrophysics 44(1):21–35
4. Aguilera RF, Aguilera R (2004) A triple porosity model for petrophysical analysis of naturally fractured reservoir. Petrophysics 45(2):157–166
5. Amyx JW, Bass DM, Whiting RL (1960) Petroleum reservoir engineering. McGraw-Hill Book Co., New York
Cited by
5 articles.
订阅此论文施引文献
订阅此论文施引文献,注册后可以免费订阅5篇论文的施引文献,订阅后可以查看论文全部施引文献
1. Exploring the Geoheritage and Geosites of Jaramara Area, Kachchh, India: a Window into the Mesozoic Rift Basin;Geoheritage;2023-12
2. Assessing the impact of bioturbation on reservoir quality: Integrated spontaneous imbibition, pressure decay profile permeability and pore-throat characterization study of the Cretaceous Bhuj formation, Kachchh basin, India;Geoenergy Science and Engineering;2023-09
3. Bioturbation changing porosity, permeability, and fracturability in chalk? Insights from an Upper Cretaceous chalk reservoir (Buda Formation, Texas, USA);Ichnos;2023-05-23
4. Geosites of the Early Cretaceous (Bhuj Formation) Based on Their Ichnological Values: Insights from the Kachchh Basin, Western India;Geoheritage;2022-12-17
5. Identification of reservoir units and their petrophysical characterization with special reference to Mesozoic formations, Kachchh offshore basin, Western India;Arabian Journal of Geosciences;2022-05