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摘要
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Abstract
Real time multi-phase flow monitoring can be economically hard to implement in a well by well basis. In many cases production controls are sporadic and distributed among wells in a common collector battery where the total production is measured regularly. Under this situation a common problem is the definition of fluid rate allocation factors with those limited measurements. However there exist physical variables, such as well head pressure, that can be correlated to flow rate and are frequently available. These complementary measurements can be used to enhance fluid rate allocation. In this paper we present a model that can be used to enhance two-phase liquid production estimates using flow rate controls combined with well head pressure measurements. This model is especially well suited for over-pressured unconventional reservoirs, where the interaction between producers can be neglected and total fluid rate is highly correlated with flowing pressure. The model can be solved using techniques from operations research and is fast enough to be coupled to a real time flow metering system in large scale.
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