The effective placement of chemical squeeze treatments in heterogeneous wells and long reach horizontal wells has proved a significant challenge, with various factors including heterogeneity, crossflow and pressure gradients between otherwise non-communicating zones within the well, all contributing to an uneven placement of the scale squeeze treatment into the reservoir. Current methods to circumvent these problems often rely on extremely expensive coiled tubing operations, staged diversion (temporary shut off) treatments or by designing treatments to deliberately overdose some zones in order to gain placement in other (e.g. low permeability) zones. As part of a multi-sponsor Joint Industrial Project at Scaled Solutions Ltd., a series of papers has been released in recent years describing the development of a near wellbore placement model, Place iTTM v. 3.0 designed to model properly the flow behaviour of both Newtonian and non-Newtonian injection fluids in the near wellbore region. In this paper, we describe the extension of previously reported laboratory dual linear core flood placement tests technology to the radial case, in which the flow behaviour of the injected fluids more closely resembles that in the near wellbore region. By extending the laboratory test technology in this way, we are able to examine directly aspects of fluid propagation in a manner which directly correlates to field behaviour. We will present laboratory test results comparing the placement of fluids with different properties and show how the results from these tests concur with previous findings and calculations from dual linear placement core flood tests, and we will further expand on the importance of non-conventional fluids for achieving improved chemical placement in complex wells.

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