Steve, based upon what I have read, there is oil and/or gas in all Shale Formations, wherever it may be … and the only real issue is whether the oil minerals can be extracted from that shale, from an economical standpoint.
So you’re absolutely correct, if the oil companies decide to bail on us right now, rest assured that they will be back, sooner or later. But they won’t bail on us once they see the results of Proctor 94 !
17,000 feet sounds more like a 10,000 to 12,000 foot vertical with a 7,000 to 5,000 foot horizontal leg to me…just sayin…
At least Concho is getting closer to my land , I have a e-mail sent to the land man at Concho with some questions , we will se if he answers them.
I believe the problem with the Red Headed Stranger is that they tried to find the absolute end of the boundry line for the Wolfcamp Shale formation and they drilled too far to the NE in Terry County and “missed the mark”.
If this is not true, then why would the same company invest another 10 million in yet another horizontal well, move over just 2. 5 miles to the SW and then permit another well, drilling 5,000 ft deeper into the shale ?
Midnight Rider … 17,000 ft ???
Actually, it will probably cost a whole lot more than 10 million to drill that well because most estimates ranging from 7 to 10 million refer to horizontal wells ranging from 9,000 ft to 12,000 ft. To go another 5,000 ft into the shale; what could that cost ??
But none of us have to guess for too much longer since Proctor 94 is clearly within the boundries of the Wolfcamp Shale and is drawing closer to completion by the day.
As I wrote early, all the producing wells in the area, tend to have higher production levels, as you move from the SW corner of Terry County, towards the NE. However, the production levels start declining again as you move too far NE (too close to the border of Lubbock County)
So if I’m right about all of this, Proctor 94 will be the well to watch and it’s drawing close to completion. If you click on one of the links that I posted below, you can see (on the map) that the NE portion of Terry County is not included in on the Wolfcamp Shale Formation so I really don’t understand how anyone could have expected promising results on the Red Headed Stranger. I’m still conducting research and trying to find the answer to that question.
The best I can guess at the moment, is perhaps they wanted to find the absolute ending boundary line of the Wolfcamp Shale and they just happened to miss it by a couple of miles.
Went by the W&T site west of Wellman. They are fracking on the first horizontal well and drilling on the second. Talked to the driller at the second and he said the shale is much harder than in other areas. Assuming he was referring to the permian basin. Anyway, here is hope that it will turn out. he did say he understood that if the two horizontal wells turn out that ultimately they could have horizontal runs every eighth of a mile. Hope, hope hope…
From anyone…what is the absolute latest on: The Red Headed Stranger…Midnight Rider…and Proctor 94?
Fracking trucks are back on site on Proctor 94. Heard that the shale was harder than expected so they are going to try fracking a 2nd time.
Thanks DB and RT for the information. Wish it had been a bit different, but “it is what it is”. SB
Thomas, I would also add language stating that you are not to blame if drilling or production interfears with grazing or if cattle are harmed. I don’t know about the going rate for grazing in your area, but most of the time, the lessee at least needs to pay enough to cover the tax’s on the land used and any maitenance ie: fencing. Could also have him refence part or all of the place in exchange for grazing rights.
As long as you disclose the terms of the O&G lease with the lessee and have him sign that he has reviewed it, you should be fine in any case. This is a pretty common situation here in Texas.
Check your mineral lease to see if there is any mention of activities as relate to grazing (usually in Surface Protection section) — particularly about building a fence (sufficient to turn cattle) around the drill site and pits (with cattle guards), keeping gates closed/locked, damage to fences, animals, protection from water contamination, not having guns onsite, etc.
Thank you everyone, many great comments. I hadn’t thought of the surface protection deal, fencing, gates, (especially around drill site), and I better re-read that mineral lease about these activities. And too, that contract with farmer covering the details.
Again, thank you all for the great advise, I do appreciate it. 
Sorry Bozeman, but the latest unofficial report I heard on Red Headed Stranger is that it is for all purposes a dry hole. Estimated production if completed would be only 10bpd, if completed. The other two sites, Proctor and Rider, I too have heard the shale was harder than expected and is probably only a matter of time before both are plugged. It is sort of the tar sands in Canada. The oil is there but it cost too much to extract the oil to make it profitable. That is why some of these early players are trying to unload their acreage on others now.
Sorry to have nothing to report on our land of any oil activity other than a company has used their 2 yr. extension we have with them.
While waiting we were asked to lease the land for grazing by a near-by farmer. Anyone know if we were to lease the land for grazing would it conflict with the oil company operation if they decide to drill?
If there is such a thing, what is a going rate of leased acreage for grazing?
Hello TA, There should be nothing in the lease agreement that concerns surface rights. Just my opinion, but I’d say fence that sucker and lease grazing to the farmer. Stipulate in your grazing lease that farmer has grazing rights so long as grazing doesn’t interfer with any drilling that might occur.
Yes, be sure to cover it in your grazing lease. A greedy lessee can cause a lot of grief.
Thank you Myranda.
I’m glad I asked the question, everyone helped out much.
Maybe it’s right about Proctor 94, I’ll be contacting Elbert soon, to see what he knows about the shale being harder than expected … but … I’ll say this;
I don’t understand how that could be … since there are a couple of wells in the nearby vicinity, pumping as high as 167 and 202 bbls per day and that those two are vertical wells.
If the shale was too hard, then how did they get those two vertical wells to pump so much ?
I don’t want to bother Elbert on Thanksgiving Day but I’ll be contacting him this weekend, cause he’ll know exactly what’s happening with Proctor.
The other well was:
Section 12, Blk C-36, Public School Lands
203 bbls per day (24 hr)
1327 bbls water
8917’ top of pay
TRINITY EOR, LLC
Where are the two wells pumping 167 and 202? and are those current numbers or was that from the 24 hour pump test? those wells could be spraberry and not wolfcamp (ie., wolfberry). w&t still fracking on the first well as of yesterday and drilling on going on the second. both west of wellman just south of hwy 213. i wish it were better news, but i still look at the 14 vertical wells w&t drilled in 2011 and all combined do not produce 100 bpd.