Replies to This Discussion

Permalink Reply by GHart on January 23, 2010 at 18:12

Are they drilling these wells like a bicycle wheel; leaving the rig in one place and going in different directions like the spokes of a wheel? And does each well cost +/- 8mm, or are there some economies of scale? Also, what is the proration unit, 640 acres per well? I noticed some of the permits having in the 400+ acre range. I'm trying to understand the drainage pattern under a normal section. Can someone help me out, here??
Thanks

Permalink Reply by James L. Williams on January 23, 2010 at 18:50

The effective frac zone around a lateral extends out 330 ft so a 5000 ft lateral drains an area of about (5000*660)/43,560 = 75.8 acres. Typically there would eventually be about 8 wells in a section drilled with laterals parallel to each other. At the University of Texas-Arlington in the Barnett Shale in Tarrant County, Carrizo says they plan eventually drill 42 wells from a single pad on Center St. It appears that the wells will go out in a somewhat radial pattern, and the laterals may be stacked because of the thickness of the Barnett Shale in that region. The pooled unit under the UTA campus is 320 acres, and as I recall, there have already been 7 wells drilled into that unit. There are also multiple wells being drilled from a single pad on the Lake Arlington Golf Course. You can see this on the RRC map.

http://gis2.rrc.state.tx.us/public/startit.htm

Permalink Reply by GHart on January 23, 2010 at 19:43

Thanks. So, when a well is completed and put into production, how do they determine the proration unit? Will they use the 640 unit size and will all the additional laterals from that pad be in the same unit? If it actually only drains about 75+/- acres, will the mineral owners under that horizontal pay zone be in a smaller sized unit?

Permalink Reply by James L. Williams on January 24, 2010 at 7:24

The mineral owners share in all of the wells drilled in the unit based on the percentage of the land in the unit that they own. Units can vary in size, and I don't know how the operator establishes the unit size. There are statutory requirements, but the operators appear to have a lot of latitude in Texas. When the operators are trying to HBP their leases they try to make the units as large as possible, and many are 704 acres (ie., 640 acres plus 10%). In some fields the horizontal well units can be larger than that. It appears that the operator can change the unit size up until his release of the Division Order after the well is in production. I'm not an expert in this; my comments are just based on observation.

Permalink Reply by eastex on January 23, 2010 at 4:12

That map is the combined gas "in place" for both the Middle Bossier and Haynesville intervals. They are several hundred feet apart, requiring seperate wells. Recoverable gas is a lot less than "in place" gas. I have heard maybe 20-30%.

Permalink Reply by jffree1 on January 23, 2010 at 4:34

Thanks, eastex, George Hartley and ALongview . I knew that the recoverable was substantially less than GIP but was not sure of the %.

Permalink Reply by farmbrad on January 24, 2010 at 8:49

The Farm Brad Report Jan 24, 2010 :
I received info last week that the horizontal phase was about to begin. I visited the Rowan 86 yesterday and it appears there's some serious casing work being done, as you can see from the attached photos. Hopefully, this well will soon bring us the positive news we're all wishing for. I've heard that the project is "looking good".

Attachments:

• Wildlife Park 2010 080.JPG, 913 KB
• Wildlife Park 2010 082.JPG, 1.1 MB

Permalink Reply by jffree1 on January 24, 2010 at 9:18

Thanks for the report and pictures, farmbrad.

Permalink Reply by Cheerleader on January 24, 2010 at 9:49

Thanks farmbrad. Please keep us up to date.

Permalink Reply by JWC on January 24, 2010 at 10:38

Thanks farmbrad. Always look forward to your updates.

Permalink Reply by JWC on February 14, 2010 at 12:36

Hey farmbrad any new news on the Rowan 86? They should be getting close.

Permalink Reply by farmbrad on February 14, 2010 at 15:39

No new information that I've heard. With the spud date of Nov 30, 2009 you would think they'd be getting close. Right now MicroSeismic Inc. is aggressively requesting permissions from LO's to implant frac reading devices on various properties. I'm hoping this is a sign of more wells to come in the area...

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