It is all about managing expectations ... and often that means...

It is all about managing expectations ... and often that means underpromising so that over delivery.

For the Wy. Permian, the liklihood or just possibility of requiring stimulation and/or/then horizontals could have been communicated to the market WHEN the shows were logged and reported... along .... with some time frames and contingent strategies for development.

If the market knew what to expect it would not overreact to news that is consistent with expectations. What is the COS of a simple stimulation and how much increase can be expected. What is the pressure of the reserviors? What is the liklihood of horizontals being required in the near term and the longer term. Geologically how similar and different is our lease to other wolfy plays? How productive have wolfcamp wells with similar shows, pressure and geology proven to be?

Here I am with some corporate and accounting type skills trying (stupidly) to be an armchair petroleum engineer.

There WAS greeny oil in Gretel. Post frac there is water displacing the oil BUT my uninformed assumption has to be that the oil is still be there. Chand .... what is your take on this?

As I posted, there are other shale plays where this kinf od water issue happens and the conventional wisdom is that you just pump the water for a considerable period of time and hope for the best. More often than not, the problem resolves itself. In BCC's case at Lee County it didn't work but what the hey....if often does. What are our options for success here or do we just assume that 1/3 of FP is water?

Also on the FP news what is the strategy moving forward? Presumably it will to progress a well on the good side of the fault line .... but let's say so and be specific and positive about it.