We got a more or less vertical well, about 3.000 m vertical depth and there you can expect a reservoir pressure of 4.000-4.500 psi. Static well head pressure was 3.000 psi. So I would expect that when they recorded the well head pressure that there was a fluid level. Not much but some (could be calculated easily for a more exact range)
Somebody mentioned that they have no tubing in the well and the flow back is produced through the casing and he/she expects that after completion that we should see a higher rate. I would not bet on that because for lifting the fluids up the casing we did not have a critical velocity problem concluded from the reports, but due the smaller tubing diameter we will have more pressure loss due to friction. That's the reason I would not expect a higher or much higher production rate.
@OldGeo thanks for the poro / perm plot. 0,01-0,1 and 1 mD at the sweet spot. Hard work for one's living. I think it could work or it could be worth to try a horizontal well and frac the hell out of it (except you got a not so homogeneous environment as for example fluviatil sediments there? In this case it's probably better to stick to the vertical wells)
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