One thing is for sure and with current flow rates around approx 250bpd this well can’t support financial sufficiency and a CR will be required if A2 flops.
At the moment they will be managing flow rate (pcp speed) to prevent drawing gas. As the well cleans up and the flow viscosity reduces (pure 30cp oil) the flow rate should increase and with a lower column density the pump may be able to be removed (as previous reports suggested it’s not adding that much differential pressure (50-60 PSI) and this is much lower than the relative to the reduced column static pressure of oil compared mixture of oil and brine). Basically following cleanup it should flow better and free flow. This is all my assumptions from a purely mechanical fluids engineering perspective and the assumption that the mixed fluid is much higher in viscosity)
Basically If A1 and A2 flops aren’t producing north of 1000 bopd in 6-8 weeks this will track sideways for another 18 months while the JV comes up with a plan for a new well perhaps a horizontal? The procurement of a CTU will not happen quickly and this will likely only become part of the for the course once and if it’s deemed necessary following results and when it can be utilised sufficiently to warrant investment in its operation and maintenance and most likely only for purposes of work over of aging wells further down the track, say once 10+ wells have been drilled.
It all hangs on A2 at the moment. Hodl
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