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Comment by Bosco Ritchie on October 4, 2011 at 10:25

Tom, the Eagleford / Woodbine section really starts to get thin in Angelina Co., however the Jurrassic is very much in play and starting to catch fire for Haynesville drillilng. Look for EOG to drill Haynesville wells soon there. the Leor well is testing Cotton Valley / Bossier, in think, and this is also in play in Angelina. There is a southwest extension of the Haynesvill play that is creeping into Angelina and I think that is the #1 play at this time. Ask me next week and it may be something different.

Comment by Tom Cates on October 4, 2011 at 10:18

Bosco, any opinions about whether productive Woodbine or Eagle Ford may extend NE into Angelina Co.? We are about 13 mi. NE of Forestar well in Trinity. BTW you guys are about the most knowledgeable posters I've read on GHS.

Comment by Bosco Ritchie on October 4, 2011 at 9:56

GOR is gas to oil ratio. The Eagle Ford shale in northern Dewitt and Karnes is deep, and makes very good liquids, mainly in the form of condensate. I believe the liquids are in a gaseous phase in the subsurface and the liquids condense out or the gas as the pressure decreases near the surface. This is good because the gas migrates through the shale easier than liquid. This acreage goes for about $20,000 per acre. Some of the Eagle Ford well in southern La Salle County make no condensate, only dry gas at a similar depth. This acreage is not nearly as valuable, and cannot produce economic wells at today’s gas prices, in my opinion.

A membrane unit is a very large contraption that filters our Co2 by pushing the gas through a membrane. They work best with low volumes and are expensive and need maintenance.

Trinity Co. has some good potential, as the Woodbine sands are productive (EAGLEBINE) and do make some condensate. It really does not matter what the price is if you can make large volumes of gas and I think this is what Trinity Co. has to offer.

Comment by Dry Hole on October 4, 2011 at 9:42

Boscoe, I am familiar with amine plants and their need for 3 ph elec. power in rural areas where it is not available etc. but please define GOR's and "membrane unit" (do these need 3 phase electricity as well ?)

Comment by Bosco Ritchie on October 4, 2011 at 9:07

Yes, blending is possible but only in very small amounts. I am aware of Enbridge buying untreated Woodbine gas in Trinity Co. but the seller is limited to 250 Mcf per day. If one wants to drill for this gas and sell gas in quantities capable of paying out the investment the gas must be treated with an amine plant or a membrane unit. All of the wells in Glendale field make Co2 in amounts that need treatment, to include Austin, Woodbine, Buda, Georgetown and Edwards. The WCS Cameron Mineral trust horizontal A/C well in Carmona field (Polk Co) had a membrane unit on it, which is a big, expensive pain. The GOR’s are running around 12 bbls per 1000 mcf. This is an issue. The wells in Houston County tend to make oil from these Cretaceous reservoirs.

Comment by Dry Hole on October 4, 2011 at 8:51

dbob, different areas and different zones will have different gas analysis I would not "generalize" a whole county  or assume that treatment was essential ----- in most cases the pipeline will purchase this gas at a discount and simply "BLEND IT AND SEND IT" blending will lower the bad PPM down to a legal level and make it merchantable. Example: take 3 wells  #1 has H2S  #2 has Co2 #3 has Nitrogen ---- if all 3 of these wells are on line at the same time their PPM could all be diluted down to acceptable levels but lose 2 wells and the operator may be forced to take the third offline ---- by the way most all commodities are handled this same way --  bad grain is blended with good grain until the PPMs are acceptable  etc. but the bad is always bought at discount.

Comment by Dry Hole on October 4, 2011 at 8:05

dbob, some limestone formations have natural fractures in them

Comment by Bosco Ritchie on October 4, 2011 at 7:59

Yes I have some gas analysis. I will scan it and post it up later today.

Comment by dbob on October 4, 2011 at 7:48

Bosco - hadn't seen that 4% number - so any gas getting produced (out of the general Trinity County footprint) is going to require significant treatment, even if otherwise "dry". Do you have access to any gas analysis for that area you can share publically? Do you see H2S as a problem?

Still trying to wrap my head around why someone would drill the lateral on those Saint Mary's wells and not frack them. Can anyone give furhter context to that?

Comment by Bosco Ritchie on October 4, 2011 at 5:55

In Trinity County, on equal depth with the activity in Houston Co., and near the county line, both the Buda and the Chalk and the Woodbine have tested gas with 4% Co2 (plus or minus). I don’t think hydraulic stimulation will change the gas oil ratio or the nature of the hydrocarbon. I wish it would!!! This is just my opinion, and I am known to be wrong on a reoccurring basis. There is obviously something going on with a change in the source material and / or the thermal maturity which changes as one enters Trinity County. I think this is why the play has not spilled over into Trinity Co. yet, but probably will as gas becomes more attractive.

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