Replies to This Discussion

Permalink Reply by Skip Peel - Mineral Consultant on March 29, 2009 at 2:59

http://www.shreveporttimes.com/article/20090329/NEWS05/903290306/1064

Permalink Reply by Spring Branch,mineral owner on March 29, 2009 at 5:52

Skip, the Sharp well is S 7 of 18/15 not 18/14.

Permalink Reply by Skip Peel - Mineral Consultant on March 29, 2009 at 6:07

Sorry, SB. My typo. You are correct. I think the KCS wells in Elm Grove are of interest. They are on opposite ends of the same township, roughly 4 miles or so apart, drilled at approximately the same time and probably utilizing the same completion design. The difference in their announced IPs is a factor of 2, approximately. Even with the relative consistency of the shale within a field or section, there is wide variance in production results.

Permalink Reply by Spring Branch,mineral owner on March 29, 2009 at 21:52

My feeling is that the difference between a 20/64 choke and a 24 or 26/64 choke can make a large difference in IP rates.

Permalink Reply by KD on March 30, 2009 at 8:47

Comparing KCS/HK wells -->

From Sonris site:

238481 R E SMITH JR TRUST 32 001
01/20/2009 10 15189 COMPLETED 1-6-09; GAS; HAYNESVILLE RA; 10,963 MCFD; 1 BCD; 20/64 CHOKE; 48 GVTY; 5370# CP; PERFS 13,244-15,120' MD; 11,322-11,343 TVD

238381 HA RA SUI;WOODLEY 8 006
03/24/2009 10 15545 COMPLETED 2-19-09; GAS; HAYNESVILLE RA; 19,050 MCFD; 1 BCD; 24/64 CHOKE; 48 GVTY; 6800# CP; PERFS 11,384-15,450' MD; 10,968-11,151' TVD

Woodley 8 is a significantly stronger well. Flowing 19MM/d at 6800# CP vs. 11MM/d at 5400# CP. Woodley choke is larger to handle more flow. Key #'s are flowrate at given pressure. Smaller CP # at Smith Trust well suggests greater drawdown on the reservoir, ie. pulling it harder to get 60% of the rate. HOWEVER...notice the perforated interval. 4000' at Woodley and 1900' at Smith Trust. Woodley 8 has 110% more perforated interval and 75% more rate. On a completed foot basis, these wells are nearly the same. Increased perforated interval suggests that there would have been significantly more frac stages in the Woodley 8 which would explain the better performance. Smith Trust appears doggier only because it has abnormally short completion interval.

Permalink Reply by Skip Peel - Mineral Consultant on March 30, 2009 at 8:53

Good assessment, KD. I missed the Smith Trust lateral length. I haven't seen one that short in a while. Have you looked at the plat to see the well location within the section?

Permalink Reply by KD on March 30, 2009 at 9:27

Proposed -->
500' FSL & 1560' FWL OF SEC 32. PBHL: 330' FNL & 1560' FWL OF SEC 32.

Note that they only completed the toe of the well. TVD is 11,200' so should be able to complete back to 11,700 or so anyway -- some time in future.

Permalink Reply by Skip Peel - Mineral Consultant on March 30, 2009 at 10:03

Very interesting. This is the first instance of an operator completing a portion of a lateral that I am aware of. Is it rare? Is there some benefit to the completion of a portion?

Permalink Reply by Jack Blake on March 31, 2009 at 4:39

I been in offshore oil / gas production for 30 years. I understand drawdown and the way you can look at ck sizes and flowrates and pressures.
The one thing that is puzzling me is why do they talk about CP on these Haynesville wells.
Surely the wells are not producing out the casing.
Wells produce out the tubing and we offshore talk about FTP and SITP.
What is the deal with CP?
Jack Blake wonders

Permalink Reply by Spring Branch,mineral owner on April 1, 2009 at 19:29

My understanding is that they do not run a tubing string in these wells. They are literally producing out of the casing.

Permalink Reply by Richard Paul Loveless on July 8, 2009 at 6:05

the state reports would indicate that there are in fact 2 3/8ths tubing strings and packers in the wells. So the question still remains what are they producing up thru? Hard to imagine that 2 3/8ths tubing could handle 20 MMCFD!

Permalink Reply by CB on April 7, 2009 at 1:43

Not that much.

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