I was wondering if anyone has been contacted concerning this well. I'm trying to figure out what I can expect next and in what kind of timeframe.

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Shutting in existing wells while drilling and/ or completing offsetting laterals is the norm for both safety as well as completion optimization efforts. Some down time is worth while if it equates to better wells with no damage or frac hits.

Yes, but if they are drilling from another pad on the opposite corner of the plat, they don't have to shut down the wells on the first pad, correct?  That is how these work isn't it? They get a set number of laterals from one corner of the plat, then move to the opposite corner and drill from there as well?

Good plat and image on the corner drilling - this would eliminate shutting down wells while drilling from the "new" corner but odds are that producing wells would be shut in while the new wells are being frac'd to minimize frac hits and damage to the existing wells.

something kinda like that picture I posted. Not saying it's accurate, just trying to express the idea.

Looks like they are pulling it out of the ground pretty good with H1 and B1.  If this keeps up, my taxes are gonna be horrendous next year.  What a problem to have though.

Getting kinda anxious to see what this next royalty payment is gonna look like. I can only imagine what you other folks are gettin that have so much more acreage than I do.  If you would've told me this was going to happen when I was buying this property in late 2007/early 2008, I would've immediately dismissed your statement as wishful thinking.  And to think, the only reason I decided to buy this property was because it was right around the corner from where a deceased high school buddy's family had a farm on 336 and I needed something else to spend my money on besides partying.  I had plans to move there when it came time to retire, but I'm not so sure of that now with a pipeline running through it as well.  Who knows?  That's still quite some time off.

Keep in mind that the first royalty payment often represents the highest life time monthly production volumes for more than a month.  It can represent one and one half to three months of production.  Thereafter the royalty will be for each individual month.  In the early years of the Haynesville play, first year declines were in the range of 75 to 80% of the projected volume for the life of the well.  The new well designs are a big improvement with first year decline in the 50 to 60% range and decline over the first two years around 80%.  The decline is basically flat at five years.

What would be of interest is the percentage of post production deductions that XTO is imposing in this unit.

I was looking at the volume posted on the RRC site. It's more than I've ever seen since it started paying.

What day was the well completed and how long was the perforated lateral?  Does that report include the choke setting?

I just looked at the PR Query.

So!  I did a little more digging around on the RRC site, and it almost looks like they are calling the B1 Shut-in still.  Is this plausible?  Could the drilling and fracking of the B1 something loose in the H1 and caused it to put out the volumes that it is now?(I highly doubt it, but I'm not a professional)  Is the RRC and XTO just being lackadaisical in their reporting and updating of information on this well? Maybe somebody who knows more can answer.



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