Replies to This Discussion

Permalink Reply by adubu on July 4, 2012 at 14:38

Jay-- of interest the well that is 10Bcf already what is it's daily mcf production still presently? Do you know what the IP was ?

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Permalink Reply by adubu on July 4, 2012 at 23:57

15 MMCFD still after 10 BCF-- WOW WOW--- any ideal what the EUR of this well will make?

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Permalink Reply by adubu on July 5, 2012 at 3:08

jay--- that's some well--- still 7mmcfd-is that correct--WOW-- what you think the EUR will be out 20 years or so

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Permalink Reply by tc on July 5, 2012 at 2:05

Jay, very informative map.  What struck me was how little developemental drilling was done.  It look like a 24x30 grid which equals 720 units and I counted only 18 units with multiply wells.  My take away from the map is that it shows how hard it will be for NG to get above $6-8 because as soon it does E&P companies will get 3 yr hedges to lock in the price and then they will all start developemental drilling and then after a year or so we will have a supply glut again.  It also shows the problems/challenges with the N LA Haynesville leasing rush, I don't know if any other shale play has so few developement wells compared to total wells drilled and developement wells are where companies really start saving on well cost and get margin expansion.

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Permalink Reply by LN on July 5, 2012 at 14:48

I can't see the map.

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Permalink Reply by Hopeful About Natural Gas on July 5, 2012 at 17:43

try clicking here to see the map

http://www.gohaynesvilleshale.com/forum/attachment/download?id=2117...

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Permalink Reply by adubu on July 6, 2012 at 14:51

Jay-- they can get $4.05 on 17 months hedge Dec 13 on close Friday HH Nymex NG Futures.

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Permalink Reply by adubu on July 7, 2012 at 5:59

Jay-- does Exco have any other leases outside of dry gas plays? But hedged $4 in proven reserves in well that will make 6-8Bcf  is better return than 10 Year US tresury of 1.6% yield--- I agree most operator as in past years always desire at least a  3-1 return or> after pay out. Of course ECXO may not have any dry powder left in bank. Is now the time to buy some good leases that others have let go for future drilling at end of the 3 years lease period ( Maybe prices of  NG back close to $5 with one year hedge near $6 by 2015-16).Or not enough "blood in street" yet?

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Permalink Reply by Carl Grote on October 15, 2012 at 5:25

Thanks for the map. I am wondering where you got the data for single wells? I've been looking on IHS and Drilling Info, but they often report cumulative production from multiple wells drilling from one pad. I need to be able assess only single well production. Thanks for any feedback.

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Permalink Reply by Hale Yayuh on October 16, 2012 at 4:33

Petra can't get individual well production if the operator reports production to OOC by unit, correct?

It always seemed to me that unit production reporting stifles exploration, because you can't tell what individual wells have produced.

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Permalink Reply by Skip Peel - Mineral Consultant on October 16, 2012 at 4:49

The Office of Conservation establishes an allowable for a production unit and allows the production to be sourced from any combination of unit wells at the operators prerogative.  Operators report production to the state based on the state's requirements which does not prohibit the operator from reporting production by individual unit well to some other data source.  Possibly API, Platts, Petra, etc.

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Permalink Reply by Chester Fairfield on October 16, 2012 at 6:33

I'm guessing you are using IHS for your data(Petra is a seperate product).  It's my understanding that for single wells that are part of a unit, IHS allocates these to the wells by using a formula they have and using data from the well tests.

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