Replies to This Discussion

Permalink Reply by Big Daddy, bcnr on April 15, 2009 at 0:39

Desoto Guy, here's a quick translation:
12/2/2008 Drilling @ a depth of 13803 feet
12/10/2008 Total Depth @ 15,158 feet
12/16/2008 set 5" (inch) pipe to 15,158 ft. WOC=Waiting on Completion rig
12/24/2008 Waiting on Completion rig (still)
01/22/2009 PERForated the pipe at depths of 14,704 to 15,012 WITHOUT FRACturing the shale. Perforations allow the gas to flow from the shale.
02/03/2009 FRACtured the shale and added more perforations @ 11,640 to 11,836 and 11,380 to 11,568 ft. Sold some gas. (Temporary to Sales)
2/11/2009 Temp to Sales
04/01/09 Waiting on State Potential. Waiting on the State to assign production constraints so the well does not drain the field prematurely.

Simple translation: Your about to get paid in a few months. Hope this helps.

Permalink Reply by Les Bamburg on April 15, 2009 at 1:57

Cannie, great job! One minor item. I think WOC would be Waiting on Cement.

Permalink Reply by Big Daddy, bcnr on April 15, 2009 at 14:52

You are absolutely right Les! Thanks. That was a quickie post right before work this morning. The coffee had not fully engaged yet.

Permalink Reply by getoverit on April 15, 2009 at 4:31

Cannie,

If a well's status is "Waiting on Completion" after setting pipe to 15,195' is the next step to perf or to frac?

Permalink Reply by Les Bamburg on April 15, 2009 at 4:47

GOI, you have to perf before fracing to put the holes in the production casing.

Permalink Reply by desotoguy on May 25, 2009 at 15:32

Hey Cannie... need a translator

COMPLETED 1-31-09; GAS; NON-UNITIZED HAYNESVILLE; 3157 MCFD; 12/64 CHOKE; 4110# FP; PERFS 11,533-15,012'; 11,197-11,198'

Thanks!

Permalink Reply by Big Daddy, bcnr on May 25, 2009 at 17:13

Well, I may be of little help on this one but here is what I think I know: Well was completed Jan. 31, 2009. It is a gas well; at the time of completion the area it is located in was not unitized for the Haynesville shale ( I would bet it is now).
Here's where it gets iffy. 3157 million cubic feet per day; 12/64 choke is an orifice that chokes down the well. I believe this is done for a number of reasons (ie, to keep pressure at acceptable levels so compression is minimal, to keep the well producing at a flatter production curve, also to not drain the field prematurely). I think the 4110# FP refers to the BOP (blow out preventer) tested pressure. The rest is simply perforations like the well above. Perforations in the bore allow the gas to flow in the casing. Hopefully this helps and if I'm wrong, perhaps Les B. can help us out. My goal is to learn 7% of what Les knows about the shale. Anymore and I'd have to change careers.

Permalink Reply by Les Bamburg on May 25, 2009 at 19:21

Hey Cannie, I think you are at 100%+. By the way the 4110# FP would mean the well had a flowing wellhead pressure of 4110 psi. This pressure is measured upstream of the wellhead choke. The flow rate would be 3,157 thousand cubic feet per day or 3.157 million cubic feet per day but I know that is what you meant to say anyway.

Permalink Reply by desotoguy on May 26, 2009 at 3:09

Thanks Guys....

Is 4110 PSI good and is that coke larger or smaller than normal?

Really appreciate it

Permalink Reply by DarBo on May 26, 2009 at 5:31

What well is this?

Permalink Reply by Les Bamburg on May 26, 2009 at 12:27

DG, the stronger wells have flowing pressures in the 6000 - 7000 psi range while the lower rate wells have been down around 2000 psi. So I consider this flowing pressure a little below average.

Choke size looks about right for that initial flow rate. Wells with higher initial flow rates typically have a choke size close to 26/64 inch.

Permalink Reply by Big Daddy, bcnr on May 26, 2009 at 14:26

Thanks again Les! I'm just the appetizer guy. You deliver the meat and potatoes. Thanks for all you do.

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