Replies to This Discussion

Permalink Reply by Bosco Ritchie on October 5, 2011 at 8:18

dbob, please find attached a decline curve on this well. It was a gas well from the glen rose, and over the life of the well it made 190,000 MCFG and 2,263 BC. Not a very good well but maybe a good place for a hoizontal drainhole!!

Attachments:

• Apple Springs Glen Rose.bmp, 1.2 MB

Permalink Reply by Dry Hole on October 5, 2011 at 14:48

Does anyone have the logs on these old HNG wells and do they show any Ohm spikes in the Woodbine that would give a clue maybe to the proximity of the "Eaglebine" ?    Also a very shallow play that I think Range was playing in not too far west of here and just south of Kennard in the edge of Houston county, wonder if that might extend on across into Trinity County

Permalink Reply by dbob on October 5, 2011 at 15:20

Bosco, by my math, that works out to an actual GOR of 83 mcf per bbl.

 

Dry Hole: there are some logs available here: http://rrcsearch.neubus.com/esd-rrc/#results

I think there some addition logs scanned out of rRC records that you might happen upon online.  

I'm still looking to find the book "well logs for dummies", so send it my way if you get the chance.

 

The working hypothesis is that the Eaglebine or related formations (Buda lime, glen rose, George town) might be productive in the area and extend further east.  The information posted recently on one of the eagle ford subgroups suggests we've got a bit higher clay content in this area, and may have issues due to the Sabine Uplift.  

 

 

 

Permalink Reply by Dry Hole on October 6, 2011 at 1:16

thank you  dbob  know what you mean about the logs ----if look at um very long you will have to go to the eye center

Permalink Reply by Bosco Ritchie on October 6, 2011 at 2:08

Dbob and Dry hole...I will give you my views (quick and dirty) on log interpretation of Eagle Ford / Woodbine shale sequences. In shale, I look for rock which has a high organic content, which generally will have a hot gamma ray (deviating to the positive) high apparent porosity and greater than 5 ohms on the deep resistivity curve. The reason we look for high porosity is that the organics are about half the density of the other shale components, so this will cause a density porosity or sonic log printed out on a sand matrix to read artificially high. If the shale does not have these properties, it is not a stand out.

The term EagleBine suggests there is layered sand in the shales. In this case the method described above will not work. To complicate things more, if the sands lens are alternating thin beds with shale in between, (laminated) then log interpretation is more difficult and that is another story.

Permalink Reply by Dry Hole on October 6, 2011 at 15:32

Thanks, Boscoe

  According to "one" EFS map these old HNG wells should be very close to "centerline" with the trend

Permalink Reply by dbob on October 6, 2011 at 16:10

Bosco

 

From my experience with soils, the laminated structure you describe might provide for enhanced permability in the sand layers  relative to the shale, but will tend to be fairly resistant to fracture migration.  Generally speaking, is that correct, or is that an over simplification?

 

Dry Hole -

 

Part of the discussion here is to try to narrow down the location of the trend, as there are some disagreements on exactly where the trend might go.  Then there is the ultimate question of where it is economical.  It would be interesting if XTO/Exxon Mobile is getting involved, as Bosco noted in a different thread.

Permalink Reply by Dry Hole on October 6, 2011 at 16:48

 I have some contacts down there I will dig -------- some of the local landmen here in Houston Co. have recognized some of the XTO people in our courthouse also -- we know of one lease taken here by Devon around the old deep Conoco Cook well acreage  ------------- Some ex XTO hands have formed their own company called Terrace out of Ft. Worth they are leasing in Houston Co. -- they may have drifted into Trinity Co.

 

  Made a trip east of Lovelady on fm1280 saw dump trucks building new location ----- went a couple more miles and turned toward Pennington on Fodice Rd and there was the Trinity county line sign so it has arrived.

Permalink Reply by Dry Hole on October 6, 2011 at 18:30

Has anyone here NOTED that Petromax (they are top IP producers and have a great website) has moved NORTH out of Madison County into mid Leon county and has had some great success following the EFS Trend Across Leon  ------ Not trying to change the subject here ---- just trying to point out that this EFS trend may be pretty wide and everyone's "map" may be correct ------ It's a long way from the Gibbs Bros.Walker Co. well on the South to Central Leon Co. on the North  (my guess 25 mls or more) and these may not be the limits.

Permalink Reply by Bosco Ritchie on October 7, 2011 at 2:55

In my opinion, the composition of the Eagle Ford shale changes as one moves east into Trinity and Polk Counties. The organic content of the shale gets very low, and it ceases to become a prolific source rock, and it loses some key reservoir properties. In my opinion, this is why we see fairly dry gas with CO2 as opposed to oil in the Woodbine AC and Buda. The suggestion is that the hydrocarbons are sourced from deeper strata and migrate up fault planes, as opposed to in place generation. There is still prolific opportunity, but one must identify a reservoir other than shale, if this is true. I don’t see this as a problem, and the Woodbine sands are present, although low perm and sometimes laminated. Tight sand is a much better reservoir than the best shale, and horizontal multistage drilling and completion works great in tight sand. In my opinion, gas prices are holding back development of Trinity and northern Polk, however, for the contrarian investor, one can feel fairly certain we are at or near a bottom for gas prices and the current market is a great buying opportunity.

Permalink Reply by Dry Hole on October 7, 2011 at 3:25

Thanks, Boscoe

    I was under the impression that a SHALE PLAY would be a broad play and prolific wells would be drilled in places that had never been drilled before and faulting would play only a small role.

 

   Now for the big question WHERE EXACTLY do you think this change in organic content occurs ?

Permalink Reply by Bosco Ritchie on October 7, 2011 at 3:41

 

I think that the very high organic content of the Eagle Ford  is found from Mexico to Lake Somerville, on the Burleson / Washington County line. As one moves east from this area, there will be diminished organic content in the EF section, but there will also be increasing sand content. In some limited areas, the organics will be sufficient to be serve as source rock and reservoir rock, but the massive organic rich Eagle Ford section which produces on northern Dewitt, Karnes area is gone.

In my opinion, the PMO production and most of the new Eagle Ford / Woodbine tests east of Lake Somerville depend on sand streaks to provide all or the majority of the reservoir, with a few exceptions. This is just my opinion, and I am known to be wrong all the time. I would be interested to see commets.

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