Replies to This Discussion

Permalink Reply by Two Dogs, Pirate on June 16, 2011 at 17:10

Mike, to my best recollection there wasn't much fracking going on, if any, in the Austin Chalk back in the day. From what I remember the chalk was naturally fracked and was much softer than shale. One of the problems, if my memory is still correct was that the well didn't need to sit very long before being hooked up to a pipeline to flow or they may silt in and stop the production. Maybe new fracking tech will come up with a way to glue the formation open. Super Glue anyone?

Permalink Reply by Joe Aldridge on June 17, 2011 at 2:38

TD,

That is my concern. When the TUSC was drilled back in the 80's the companies would "mud up" the AC when drilling down and then would come back and try to produce it. We never got any production from any of those wells. Yet we know the oil is there. So my concern is that with long laterals the formation will get "mudded" up and damage will be done to the formation. I think my solution would be to sand/gravel pack the formation on the way down or while drilling so you have something to build mud cake on.  I'm no engineer but that sounds like that might work. That would also hold the formation open after drilling and keep the formation open. Your thoughts on this.

I talked to a gentleman her last night that said people East of Zachary in East Baton Rouge Parish are getting letters and phone calls from at least two companies. The letter is from WEXCO out of Dallas. They are offering $200 dollars per acre for a paid up 3 year lease with a 2 year option to extend with 17.5% royalty. Any information on the company would be good to know.

Permalink Reply by Two Dogs, Pirate on June 17, 2011 at 8:59

WEXCO does leasing and title research for the E&P companies.

Permalink Reply by Joe Aldridge on June 20, 2011 at 16:33

Mike,

I have never heard the term "rubble" used before. I'm assuming that by "rubble" you are talking about broken up formation that is being washed up not drilled up. That was the problem in the Amoco - Lorman well that blew out in the late 70's near Zachary and killed two crew members. The well Super that came in to try to salvage the well after the blow-out told me that the crew had been washing up formation the size of the end of your thumb and was having problems maintaining circulation before it blew-out. Was that the case in the well you are talking about?

 

Permalink Reply by Joe Aldridge on June 20, 2011 at 16:47

Can anyone clarify the choke size. That would be a V E R Y Large choke at 408/64. 40/64 would even be large but probably about the right size for that production.

Permalink Reply by jffree1 on June 21, 2011 at 2:07

Joe, it was 48/64.

Permalink Reply by Robert L Call on June 27, 2011 at 5:09

Mike R  - I'm just starting to follow the CV, Haynesville, Tuscaloosa plays.  I have a small mineral interest in Rusk County.  I have been working the Bakken in ND & MT recently.  In NW ND they are running laterals 10,000 plus ft on 1280 acres drilling units (1 mile by 2 mile rectangle) and doing 20 to 30 stage fracs.  Average IP's are in the neighborhood of 1500  to 2000 BOPD, 1000 BWPD and 3 to 4 MMCF PD. Because there are no major pipelines in the area and thus no gathering systems the gas is flared.  Such a waste. These wells fall off rapidly and level out at about 500 to 800 BOPD.