Ann: Operations Update, page-282

What one will find Db is that with the fractures being larger towards the production liner/ well bore they will initially hold 100% frac fluid.

As the frac fluid retreats from the fractures IF the reservoir has the required over pressure there will be a zone of intermingled frac fluid with hydrocarbons following the 100% fluids.

Its interesting to contemplate the 30% figure if this is what is observed.

That leaves 70% of the frac fluid to come minus any that the reservoir might take up or soak.

But even so this may be an indicator that the fracture network is extensive if such a large proportion of frac fluid has been consumed by smaller complex fractures that interface with the reservoir hydrocarbons. Even if 40% of the fluid has hydrocarbons intermingled it may reflect a good complex fracture network.

I cant help thinking the pressures at this depth, even on plain fluids, let alone fluid/gas mixes must be immense and if the reservoir is pressure communicating then its also hard not to extrapolate this thinking to what the hydrocarbons will do once the stimulation fluids have been cleaned up.

d.