One thing for sure, if the results are questionable, WT will do the same thing they did last year after the 12 verticals they drilled turned out to be less than hoped. They just said that the results were under evaluation.
Still hoping 2013 turns this more positive than 2012…
Did you guys notice too, though, that all these “public market release” statements are so vague that they are essentially useless?
At least on my end, I knew as much before reading the statements than what I knew afterwards. It’s probably gonna stay that way for several months.
I would venture to say that the only way we’re gonna learn anything reliable is when some of the mineral owners start to receive their royalty checks.
I would think even then, I’d want to be extremely vague with any details that I let out as a mineral owner.
Just noticed that last month, Red Willow Production Company got a permit for a vertical well on Noble 134. Anyone know anything about this?
Which WT vertical wells are listed? Looked on the RRC GIS map viewer and I could only see one listed as a producing well and there were no records listed for that well. It was located just west of the two horizontal wells they are developing. I must be on the wrong site…
What did we hear new on the Proctor. Did the new fracking crew from South Texas make it to town yet.
Where is Noble 134?
Why does the Proctor need a fracking crew from South Texas?
Sorry to hear that about the Proctor, but I told you so a while back that it was going to be a dry hole because of the lack of activity there etc. Beginning to look like that any wells drilled in far west and northern Terry are in a payload zone, but once you moving east toward Brownfield, the rest of the county is completely out of any production zone. That stinks.
Noble 134 is located west, northwest of Wellman (five miles west on 213, then about 3.5 miles north) or southwest of Brownfield. API 445-32356
And Noble 134 is a horizontal well permit…
Heard this morning that 2nd frac on Proctor not good and operator to begin plugging operation.
RHH, Thanks for the info.
I think that everyone will be happy with what happens in the next few months in Terry County in the east and north part of the county. After all, there has not been any plugging yet but the oil company may plug one to keep prices down to an oil company buyers market. I will put some info up in a few days when I get time. Every bit of info, good and bad, that we all hear lets us all have a clearer picture of what is going on. There are still lots of minerals that are not leased in Hockley, Terry, Lynn, Gaines County. The oil companies have invested multa multa millions and are just now getting started. Watch the Clyne Shell site. In North Dakota, they are drilling as many as 16 horizontal wells on one well. Only the oil companies know what they are about to do. It has been said that Empressa put 400 million when they bought leases in our area. This is just a drop in the bucket. They have only drilled two wells in 12 months. Robert, lack of activity in this is not right. Look at all the wells around Locket. Yates has drilled 4 or 5 horizontal, 3 horizontal west of Wellman. The oil companies’ new budgets should start showing action soon. Who knows, but the money is being spent looking for the black gold.
I agree with e dubose. The oil companies don’t like letting go of their money very easily, so if they’re spending, they have information on something there. Rumors, good and bad, will spread until checks start coming into people. Some are started by the companies themselves, and some just get stirred up. There has been oil here in the past, and our technology has advanced so much that I think something will happen soon. Just a crappy waiting game sometimes.
Based on the information that I’ve been reviewing, it’s quite the opposite.
From what I’m looking at, the Wolfcamp shale production rates are the highest in the southwest areas of Terry County, and once you move towards the north, particularly the northeast, the production falls down towards the 10 to 30 bbl range.
If they are actually plugging Proctor, that is one that I will have to see to believe because based upon my own research, there is no such thing as a dry hole when drilling inside shale formations. Couple that notion with the fact that Proctor was a horizontal drill and I’m just not buying the recent news rumor of “dry hole.”
We’ll see!
In my opinion, the oil runs dry in the far northeast portions of Terry County, but all production reports at the Railroad Commission site show there is good or decent oil production in all areas except the northeast corner, which is right close to the Lubbock County border.
Also, the tip-top northern portions of Terry County don’t seem to produce well.
But then look at the Wolfcamp Shale map and take notice of where the boundaries of the shale formation are located.
The Wolfcamp Shale formation fails to extend up into those areas.
Not sure what the maps show, but I am more concerned with what I heard from the verticals drilled in 2011. The oil may well be in the shale, but the geology of the rock will dictate how much oil can be recovered. Regarding the Cline Shale play in Scurry, Borden, Mitchell counties, I have heard that this could be comparable to 10 Eagle Ford Shales stacked on top of one another. Wish that were farther west too!
RHH – which means the issue of low production rates could be associated with the skills, knowledge, and expertise of the geologist rather than how wet the shale is.
It could take several years for the geologist to determine the best depths and spacing between the fracturing. We have seen a few high production wells showing up on the RRC website so we know there’s oil there and plenty of it.
Let’s just hope now that the geologist can get the oil flowing before the investors are scared out of town.
Or all of the above. Bottom line, you are trying to crack a rock some 250 million years old that is 12,000 feet below the surface. Rock changes from area to area and I think what we are seeing is what was working south of Midland and extremely successfully in this same basic formation isn’t working the same way in Terry County. That points to a difference in the rock. And yes they do learn with each and every well drilled, I just hope we would start seeing some positive results. Like you, I don’t want to see the money get tight and they move to Cline Shale play…
That is encouraging news and happy to hear it. I’m currently under lease with Shell in Lynn County, on FM 213 about 2 miles east of Terry County line and Dawson County line less than 10 miles south. RRC reports the Shell Stephens well as a shut-in producer with no production data on the W-2 filed in December of last year. Dunno if they found a way to not have to report initial production or it’s a dry hole and they’re trying not to have to pay the fees.