Razorback, Howdy
I looked back through the postings and found it at #5474. I don't see them mobilizing a rig back here in the near future...they know that they have oil here, and that some remedial work is in order. For the same reason, I doubt seriously that they'll P & A the well. After all, it probably cost them $2.5 - 3 million to drill and test this thing, so they won't walk away from it - it's just sunken costs.
16 m of net pay is no barn burner of an oil well - especially when some of it is in a zone that's been poorly cemented. Notice that they didn't release the flow rates and flowing pressures, both of which are very important parameters when assessing a play.
Bad cement jobs are shown up by cement bond logs, which are in themselves very qualitative things, meaning that different people commonly arrive at very different conclusions when looking at these logs. If you have a bad cement job, the only thing you can do is squeeze in more cement, then re-perforate. The historical odds do not favor success.
If the cement job is in fact O.K., then the appearance of water after the initiation of oil flow suggests that the well was pulled down too hard, and water coning resulted. This is a form of formation damage which can be only partially ameliorated (Whoa! Big Word). Any of these problems can be properly diagnosed, given the right wireline tools (temperature and sound logs, as well as cement evaluation tools).
Geologists are always waving their arms and moaning on about the appearance of oil in sidewall cores, when the formation often is, in fact, as dry as a popcorn fart. This peculiar form of romance is a chronic malaise to us drillers. The oil was here, but now it ain't, that's the point. It may be updip, but then again, it may be updip enough to be off the lease, too.
Gig'Em |
