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<p>This paper explores a quantitative method to estimate reservoir-body connectivity between turbidite channel complex and slope system, and describes its impact together with stratigraphic architecture, internal geometry, and other geological attributes on oil recovery and waterflood performance. Cores from two wells provide facies logs that guide correlation of wireline logs to create three channel architecture scenarios and input for object facies modelling spanning 16/07a-B1 to 16/07a-B14. Model grid comprises 43 cells and 46 cells in the horizontal directions and 100 cells in the vertical direction. Each cell is 20.0 ft (6.1&#xa0;m) along horizontal directions and 6.1 ft (1.9&#xa0;m) along depth. Net-to-gross, porosity, and permeability were simulated using Sequential Gaussian Simulation. Displacement strategy involves injecting water in 16/07a-B14 and producing oil from 16/07a-B1 at equal rate of 20,000 BBL/D for 5 years. Findings reveal that lack of overbank sand bodies in <i>single-storey</i> turbidite channel architecture reduces overall connectivity despite high net-to-gross channel fills. High vertical connectivity in slope system encourages prolonged smooth oil displacement, sustaining oil production rates over extended period of time to make this architecture most desirable for development. <i>Multi-storey</i> and <i>multi-lateral</i> turbidite channel architectures suffer from early fingering of waterflood fronts, prompting injected water to preferentially sweep laterally continuous sand-rich levees and high net-to-gross channel fills while bypassing slope and margin deposits because of large permeability contrast between them. Thus, oil displacement strategy in these reservoirs must effectively control water production to slow decline in oil production rates and produce more oil in the long term.&#xa0;</p> Graphical Abstract <p></p>

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The impact of stratigraphic architecture on static connectivity and reservoir performance in a turbidite channel-to-overbank system

  • 期刊论文

  • 发表日期：

    2026年4月8日

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  • Bayonle A. Omoniyi,
  • Dorrik A. V. Stow

摘要

This paper explores a quantitative method to estimate reservoir-body connectivity between turbidite channel complex and slope system, and describes its impact together with stratigraphic architecture, internal geometry, and other geological attributes on oil recovery and waterflood performance. Cores from two wells provide facies logs that guide correlation of wireline logs to create three channel architecture scenarios and input for object facies modelling spanning 16/07a-B1 to 16/07a-B14. Model grid comprises 43 cells and 46 cells in the horizontal directions and 100 cells in the vertical direction. Each cell is 20.0 ft (6.1 m) along horizontal directions and 6.1 ft (1.9 m) along depth. Net-to-gross, porosity, and permeability were simulated using Sequential Gaussian Simulation. Displacement strategy involves injecting water in 16/07a-B14 and producing oil from 16/07a-B1 at equal rate of 20,000 BBL/D for 5 years. Findings reveal that lack of overbank sand bodies in single-storey turbidite channel architecture reduces overall connectivity despite high net-to-gross channel fills. High vertical connectivity in slope system encourages prolonged smooth oil displacement, sustaining oil production rates over extended period of time to make this architecture most desirable for development. Multi-storey and multi-lateral turbidite channel architectures suffer from early fingering of waterflood fronts, prompting injected water to preferentially sweep laterally continuous sand-rich levees and high net-to-gross channel fills while bypassing slope and margin deposits because of large permeability contrast between them. Thus, oil displacement strategy in these reservoirs must effectively control water production to slow decline in oil production rates and produce more oil in the long term. 

Graphical Abstract