Polymer injectivity is a critical parameter for implementation of polymer flood projects. An improved understanding of polymer injectivity is important in order to facilitate an increase in polymer EOR implementation. Typically, injectivity studies are performed using linear core floods. Here we demonstrate that polymer flow in radial and linear models may be significantly different and discuss the concept in theoretical and experimental terms. Linear core floods using partially hydrolyzed polyacrylamides (HPAM) were performed at various rates to determine in-situ viscosity and polymer injectivity. Radial polymer floods were performed on Bentheimer discs (30 cm diameter, 2-3 cm thickness) with pressure taps distributed between a central injector and the perimeter production well. The in-situ rheological data are also compared to bulk rheology. The experimental set up allowed a detailed analysis of pressure changes from well injection to production line in the radial models and using internal pressure taps in linear cores. Linear core floods show degradation of polymer at high flow rates and a severe degree of shear thickening leading to presumably high injection pressures. This is in agreement with current literature. However, the radial injectivity experiments show a significant reduction in differential pressure compared to the linear core floods. Onset of shear thickening occurs at significantly higher flow velocities than for linear core floods. These data confirm that polymer flow is significantly different in linear and radial flow. This is partly explained by the fact that linear floods are being performed at steady state conditions, while radial injections go through transient (unsteady state) and semi-transient pressure regimes. History matching of polymer injectivity was performed for radial injection experiments. Differences in polymer injectivity are discussed in the framework of theoretical and experimental considerations. The results may have impact on evaluation of polymer flood projects as polymer injectivity is a key risk factor for implementation.

A programme of thermal developments is being rapidly matured in Petroleum Development Oman's (PDO) Southern Oil Directorate. This targets several billion barrels of heavy oil deposits in clastic reservoirs at depths between 800m and 1800m. Cyclic steam stimulation and steam drive applications dominate the current development program. High-pressure steam injection and air injection applications are also pursued in some fields through studies and laboratory experiments. Steam trials in three heavy oil fields spearhead the thermal developments and results are presented. These steam trials provide further insights to optimise the ongoing full field developments. The paper also describes a portfolio management approach to thermal developments, given that many of the target fields are in close proximity and can share the same infrastructure and development methodologies. One of the main heavy oil full field developments has been matured from a Feasibility stage to Final Investment Decision in just three years. In this particular case, unique opportunities and challenges for thermal development arise due to the depth and thickness (200m) of the heavy oil column, with an underlying large regional aquifer. Specific topics addressed include thermal well cost reductions, urban planning, minimising additional gas requirements through COGEN, water management, development of a new Operating Model for Lean Steam Well & Reservoir Management and Operations, and overall integrated project management.