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• W2076316910 abstract "Abstract In this paper, we examine the monitoring of a moving interface problem in immiscible floods in 1-D heterogeneous systems. The solution is presented for monitoring saturation fronts in an extended case of a classical 1-D Buckley Leverette with various lateral permeability profiles. Flood is assumed to be at a constant injection rate but with the opportunity to continuously monitor injection pressure, fractional composition of produced fluid and production ressures. Lateral changes in effective transmissibilities between the injector and the producers caused by movement of immiscible fluid-fluid interface and detected from the solution of interference pressure equation provide an added dimension for tracking the saturation fronts. The effect of the rock heterogeneities is filtered out by analysis of the incremental changes observed with respect to the base measurements at the early stages of the flood. Introduction Single well and multi-well pressure transient tests have traditionally been used to characterize reservoir rock heterogeneities assuming single phase flow. Extensions to multi-phase flow were first addressed by the pioneering work of Perrine and Martin 1–2. For single well tests, subsequent works by Ramey et al 3,4, Kazemi et al 5 focused on detecting movement of the injection front from single-well tests. Analysis of multi-well tests for characterizing two-phase flow has not received much attention mostly due to the fact that the process of data gathering has been limited to special circumstances of interference analysis when one or more can be shut down for observation purposes. In such cases, what is estimated is the average values of transmissibility and storativity between active and responding wells at a given point in the life of the field. To extend the capability of multiwell tests in the tracking of the dynamic flood front, it is necessary that we do a continuous monitoring of rate and pressure data. Thanks to the recent technological advances in smart wells and the ability of placing various sensitive sensors in the injection and production wells, there is now a practical paradigm for front tracking via interwell tests. From the interpretation point of view, nonetheless, describing multiphase flow systems is complex because of the need to in-situ relative permeability characteristics that define the interaction of the multiple phases 6–12. The relative permeabilities in immiscible systems are non-linear functions of saturations 13–14. Furthermore, while in the single-phase flow only a single equation is required to obtain the flow dynamics, in the multiphase flow, multiple equations are required to describe all phases 15–16. These equations, when combined with the relative permeability functions, can in some cases become nonlinear and analytically intractable. A particular case of well test analysis on multiple wells is interference testing which produces an estimated permeability profile across the reservoir 4,17–19. Once the effective directional reservoir permeability is mapped, such test can potentially help in reservoir fluid flow monitoring. In this Study, we investigate continuous interference testing in a multi-phase flow (water-oil) for reproducing the permeability profile across a one dimensional reservoir. Essentially phenomenological and intuitive, our approach relates the immiscible flood front location or transmissibility variations across the reservoir to the continued recording of pressures in production wells. In contrast to conventional interference testing, which requires shutting in some active wells and hence affecting the field operations, our approach shows how continuous monitoring of rate and pressure across the system can be used to locate the shock front and how, based on the location of the shock front, a permeability profile can be obtained by monitoring the real-time pressure profile." @default.
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• W2076316910 date "2007-10-28" @default.
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• W2076316910 title "Detecting Immiscible Flood Fronts in Heterogeneous Systems from Continuous Monitoring of Rate and Pressure" @default.
• W2076316910 doi "https://doi.org/10.2118/111238-ms" @default.
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