Updates
January 28, 2014: longer extended laterals, and these are now being drilled because they are under the river. Also, note:
March 28, 2011: A couple days ago, I got into a conversation with "anonymous" over the fact that the operator had lost contact with the gamma detector, and decided to press on anyway. My hunch is that this is not all that unusual. I just happened to look at the file report for the Murex Ventura 11-2H well (#19196). From the report: "A tool failure rendered gamma data unreliable and a decision was made to continue drilling the remainder of the lateral without this information." Gamma was lost at 19,460 feet; TD was 20,420 feet.
March 26, 2011: For an update on this well, go to this site, and look at the first two comments. An alert reader noted that "they" lost contact with the gamma detector at about 21,884 feet but pressed on anyway, without the gamma detector, and reached TD.
It will be interesting to see if the yield will be 3X of a short lateral. And I wonder if the frac crews can handle a 3 mile long horizontal.
ReplyDeleteTime will tell.
The amount of oil produced by a horizontal, all things being equal in the Bakken (and, of course, they aren't), are dependent on a) natural fractures; and, b) quality of manmade fractures.
ReplyDeleteBecause of the disparity between/among natural fractures, we will never be able to do real head-to-head comparisons (law of large numbers will help).
On the issue of manmade fractures, it is certainly my impression some frack crews are better than others.
I would assume the size of the pipe/choke makes a difference. If three times the amount of oil is there, the pipe/choke might be another limiting factor.
But, like you, I will be watching this well with anticipation. If I forget, remind me. Smile.
Thank you for writing.