@butcherano. Reservoir quality (poro-perm) may be uncertain, but with reference to the chart below, you will hopefully appreciate that it is possible to classify a reservoir as conventional in the 1 mD to 20 mD permeability range with viscosities in the range 1 - 1.5 cp. So, this chart conveys a message that Mukuyu would be a conventional reservoir even when the fluid is 1 cp oil viscosity if the perm is on the range 1-20 mD or more. Based on my estimates, the Mukuyu gas condensates may have viscosity around 0.025 cp, therefore much more capable for natural flow.
Some weeks ago, you referred to a reservoir in the Perth Basin which did not flow even though the permeability should have been sufficient to achieve conventional flow. My belief is that there was skin damage, but require well test results to confirm. If skin damage was present, it is a shame you did not attempt reperforation using propellant guns such as Pulsefrac to remove the near wellbore damage.
I firmly believe the Mukuyu sands are capable for flow especially if permeabilities are in the range 1-20 mD or more. Nevertheless, as I've mentioned several times in the past, having backup Pulsefrac/Stimtube capability and/or hydraulic fracturing equipment would be a great way to help maximise the flow potential. In addition, fracking the lowest porosity zones in the future could add significant net pay because no mobile water has been found at M-2.
