We investigate the concept of inverting certain wellbore measurements acquired during the normal process of production to infer the distribution of inflow along horizontal wells traversing heterogeneous formations. We consider measurements that are in principle feasible with fiber-optic sensors. Besides distributed temperature-sensing systems that have an established deployment record, we also examine wellbore pressure sensing at multiple points, which is nascent technology. One outcome of our analysis is broad requirements of such systems, such that they can be used in diagnosis of flow problems relevant to horizontal wells. We investigate this problem by modeling techniques encompassing multiple physical phenomena in the coupled wellbore-reservoir media (flow, thermal, and compositional), and associated inversion techniques (pressure and flowrate). We confirm the informative character of multipoint flowing pressure for liquid influx detection, liquid-liquid discrimination (under certain conditions), and also establish magnitudes of temperature effect associated with influx of gas-liquid mixtures. Results indicate the problem of two-phase influx in horizontal wells can be reasonably resolved with the method proposed in this study. Further work, however, is required to refine certain aspects of the methodology. We briefly address the implication of this methodology with respect to conventional methods, i.e., production logging.

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