An important issue in the management of oil and gas reservoirs is ways to maximize the areal sweep efficiency during injection processes. As such any imaging mechanism to map the interface movement is a great help. To obtain this information, limited number of tools exist and it is our expectation that the extended application of interwell pulse tests can provide better insight into the flow boundaries. The improvement of sensor technology and data mining opens up new opportunities to obtain very useful information from continuous recording of data at the producing wells. In reality, each injection well can be subjected to pre-scheduled or unsupervised rate changes. These rate changes create pulsation in the reservoir. On the receiving end the producing wells, according to distance and formation and fluid properties between wells, detect the pulse but with a delay called the time lag. Our hypothesis is that the tracking of the time lags could be indicative of the injection fluid front plus indigenous reservoir properties. To separate the two effects, we postulate that a comparison of time lags with the first available time lag could primarily relate to front location. The difference between displacing and displaced fluid properties, cause different time lags. Our approach to this problem is combination of analytical and numerical solutions. The analytical experimentations can calibrate the numerical solution. Linear and radial flow geometries both for homogenous and composite reservoir have thus far been studied. The result of these systems demonstrate the potential of the proposed approach.


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