Replies to This Discussion

Permalink Reply by jffree1 on December 10, 2010 at 3:49

The next step would be to frack the well to release the gas.  If a gas gathering line is already in place they will then tie into the gathering system.  If the gathering line is not in already, the well may be shut in (before frack) while waiting on the pipeline.  Hopefully, you will hear well results sometime in the next 3-4 months. 

It is too early to start hunting production from the well but you can use the time to learn your way around the TRRC website if you are so inclined.

http://www.gohaynesvilleshale.com/group/trrchelpcenter

 

The well was first permitted, by XTO, as the Rebels Deep Unit #1H.  That permit was cancelled and now Exco is the operator of the Rebels Shale Unit #1H.

Here's a link to the well permit page.

http://webapps.rrc.state.tx.us/DP/drillDownQueryAction.do?fromPubli...

You will need the various numbers associated with this permit in order to track production later.

 

 

 

 

 

Permalink Reply by Madeline Borzilleri on December 10, 2010 at 7:34

Thank You so very much!

Permalink Reply by adubu on December 10, 2010 at 11:39

Madeline--do you have minerals that are in this unit? If so as royalty owner in unit call who leased it from you ( did you lease with XTO, EXCO ,or someone else)and ask to speak to person that is in charge of production/exploration of that well. Generally they are informative to royalty (mineral) owners in the unit. Be nice and ID yourself and your lessor information.

If you are just interested  observer or with minerals close to this well then you like us will just have to wait until things are reported as jffree1 outlined above

Permalink Reply by Susan Tolles on January 24, 2011 at 6:53

This was in yesterday's report in the Tyler Paper.

EOG Resources completed the Tolles Well No. 1 to 10,700 feet 13.2 miles southwest of Center in the Naconiche Creek Field. On a 24/64-inch choke the well potentialed 839,000 cubic feet of gas. Production is in the Rodessa-Travis Peak Consolidated.

Looks like it is not a huge well compared to some of the others, but at least it has been completed. Can anyone give me some insight on what happens next?

Also, this well only used a small portion of the total amount leased by EOG. The lease expires in February, so does that mean that the balance is up for re-leasing, or does this mean that all of the leased minerals are tied up since they have a well on part of it.

Permalink Reply by intrepid on January 24, 2011 at 9:36

Don't be too disappointed yet. This is still a good area and it is in the Rodessa-Travis Peak so that may account for the low IP.

 

As to the question about the remaining acerage under lease, I would think you have now been 'hbp'd'.

Permalink Reply by Susan Tolles on January 24, 2011 at 9:50

Okay, I'm new at this. What does "hbp'd" mean?

Permalink Reply by adubu on January 24, 2011 at 11:54

Susan--- HBP= "Held By Production" means as long as production in commerial amount your lease is extended as long as there is production. You need to call EOG and see if all your minerals have been put in the lease. You will get a Division Order soon. 839,000 cfd is fair for Travis Peak well it will then make about 1 BCF over next 20-25 years. They can drill a well every 40 acres in unit and they will over time when NG get back in 7-8 range. Plus can drill deeper into shale, etc other formations unless you have a depth clause in your lease then they would have to release everthing below depth drilled depend on what your lease says.  Any acres not in the unit will be released after expiration date but I bet they will put all in the unit if they are contiguous acres with the unit.

Permalink Reply by Susan Tolles on January 24, 2011 at 12:29

Thanks so much for that great explanation! At least there's something there, and good prospects for the future.

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