Haynesville Shale tighter rock that we thought

I heard from good source that EOG and XTO are drilling wells (East Texas )  in Haynesville shale with only 50' spacing between lateral rather than 330' because Haynesville rock is so tight they are able to Fac and drain only about 25' that would mean about 30 wells in unit rather than 6-8. I understand pressure and flow are at virgin levels just 25' feet from other fac H hole same depth.WOW if true we got a hell lot of Nat Gas. 

Jay, other Geologist please weigh in your thought and what you have heard. Skip you know anything along these lines???????? 

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Permalink Reply by Skip Peel - Mineral Consultant on August 2, 2014 at 16:53

Ever seen a Haynesville Shale core?  It's as dense as the tightest concrete you've ever seen.  It doesn't look like it could hold much of any hydrocarbon the pore spaces are so small.  And the permeability is so tight it is measured in milli-darcies.  I'll let Jay weigh in on the possibilities of down spacing but I've never heard of 50' spacing or anything remotely close to it.  Doesn't sound right to me.  Many Haynesville Shale operators have mentioned the possibility of up spacing meaning fewer wells to produce a given volume of rock.

Permalink Reply by dbob on August 3, 2014 at 3:20

Some of the surface locations are within 25' to 50' of each other, but involve laterals stacked at least a few hundred feet vertically in the play.  Thats my best guess on the origin of the rumor.

Permalink Reply by Skip Peel - Mineral Consultant on August 3, 2014 at 3:25

With pad drilling the incidence of closely spaced surface locations has become quite common.  I think you're correct, dbob.

Permalink Reply by jffree1 on August 3, 2014 at 4:15

It might be possible, rule wise, in stacked laterals so it would be a vertical spacing of 50'. Horizontal spacing rules haven't changed, that I have seen, and LA & TX have very similar rules in that regard. XTO & EOG are the only ones doing stacks in the HA over here right now but I expect APC may follow suit before long.

Permalink Reply by jffree1 on August 3, 2014 at 5:08

I just looked back over the plats for all the wells drilled by EOG in Panola Co. (the only place they have drilled in ET in the last year) and none of those wells have a unusually close spacing, per the "as-drilled" plats, and none were stacked laterals. Someone is confusing/conflating two different aspects of well bores (surface locations vs. path) into a new theory. I've attached a plat which shows five out of seven wells drilled in these units.

Attachments:
Permalink Reply by jffree1 on August 3, 2014 at 6:04

Here is an example of XTO stacked laterals (6) in San Augustine County. Just my humble opinion... if XTO has drilled stacked laterals just 50' apart vertically... it was done either by accident or, if deliberate, to test the communication between them.

Attachments:
Permalink Reply by adubu on August 3, 2014 at 12:13
jffree 1
All that makes sense I' get confirmation in couple weeks and let all know
Question what are these 1B wells XTO permitting ?
Permalink Reply by jffree1 on August 3, 2014 at 12:39

They are stacked laterals. They have changed up their well numbering system, amending well numbers on existing permits and doing away with the #_HB style, it appears. I am still trying to get a handle on it so I can't tell you for certain except that one friend theorized that the B in a well # now indicates a Bossier completion. Don't know yet if that is correct or not but it is a possibility.

Permalink Reply by adubu on August 3, 2014 at 3:31
Dbob, Skip if you have contacts with anyone in EOG or XTO --please check this out
No they are not S/L in two different formations bossier/haynesville but are in haynesville same depth. Info from a crew member of wireline co. involved with fac completion of wells
Time I am sure will tells us
Remember you hear it first on this web site if true
The person I heard it from is reliable
Maybe jjree 1 who follow rigs and well in area may have some info on this
Permalink Reply by Skip Peel - Mineral Consultant on August 3, 2014 at 3:46

A frac cylinder with an effective radius of 50' would provide little reservoir contact.  And hydrocarbons don't flow to a wellbore in tight, unconventional formations except through artificial fracture networks. 

Permalink Reply by adubu on August 3, 2014 at 3:56
Skip
That the point if can fac only about 25' (50' radius)and get 10+BCF from 5000' lateral then it's very tight and there is a hell lot of gas in formation
Or I am missing something in your comment?
Permalink Reply by Skip Peel - Mineral Consultant on August 3, 2014 at 4:00

That's a supposition unless you have a specific example to offer.  If you can find some GIP data that would help to make your case.

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