I was told that ‘a long time’ to drill a well with the usual difficulties is about 30 days. So there was some sort of problem with Monster like they got stuck or (gasp) needed to fish something out or had to sidetrack. 12-15 days to drill a two mile lateral is about right. Permian information. Your results may vary.
William1 yes pipe line in the ground going under hwy 77 to Phillips 66 line. It’s been hydro tested and tied it should be hot. Got 3 gates in my hay patch last week just need lock combination.
Definitely has to be 5.5 inch / standard for production casing
Any idea how big of a line diameter wise?
Monster did have issues…a bunch, more than Parr did. I heard it was not a equipment issue but difficulties in the formation going east once they started the lateral.
Was told Remeirs was a piece of cake compared with Monster. Redhawk now hesitant on how far east they want the “new” units. Our “maps” might be changing depending on frac results of monster…could be a slight westerly shift.
They were also debating the plans of going east of Lavaca river…which would be north of Chapman unit…and going up to Parr. Talking just putting one unit from the Matrix units in richerson survey to the east ending at the west boundary of the Lavaca river and west of FM 957…. IMO they will still try it since Parr is said to be a “productive”well after the fixes…but not a 7.5 month payback as planned. Again talk amongst the “junior executives” not the main decision maker…..and this was the discussion before Parr flowback even started….so hopefully Parr results have put those units back on the “map’.
PS Note - Rumors are that Stone Ridge Energy is the buyer of the Baytex assets
Yes, heard the same thing.
This website won’t allow links without mod approval (which is probably a good idea). So I’ll just say that the Baytex wells are probably being bought by stoneridgeam with flywheelenergy as the operator.
Washington Irving–you scooped me on that one….I too believe Flywheel energy (another private company) will be the operators for Stoneridge energy…even though flywheel is base in Oklahoma. After Stoneridge bought the ConocoPhilips Oklahoma assets for 1.3 billion they got Flywheel to operate it for them, and Flywheel also just took over some major tracts in Colorado recently. Looks like Flywheel is all about nat gas. ..and Stoneridge asset management who owns Stoneridge energy is heavily into Bitcoin and based in New York. If not Flywheel operating the EF assets Stoneridge will have another company do it….
I have quite a few tracts operated or leased with Baytex so I am concerned about this transaction…they need to keep the PennV/Ranger/Baytex team so they can continue to have good results…although they are now down to 1 rig.
They’re purely buying it for the production (PDP), that’s their MO
Pecan pad looking empty rig layed down last night. Talked with truck driver that had a load of skids said he was going.10 miles to Witting.Tx Also talked with escort driver with wide loads he said they going to Smiley Tx down by Yorktown Tx. Now it’s wait and see what the fracking does.
Rig heading into the guts of the Eagle Ford trend.
It will be interesting to see if frac’ing is delayed until gas line is in place / better to flow in gas line to sales instead of flaring gas.
You can keep an eye on the frac completions at www.fracfocus.org. Use the advanced search option.
Went to Maddox/Chapman+2 pad today. Entrance is off of CR 189…and it has a long, long road going to the pad. The pad has a lot of equipment on it and there were 3 trucks moving along the new road I could see headed toward the pad. Was told earlier that the rig on Francis pad is drilling the last of the 4 wells (3 new) and should be moving to the Maddox pad in the next 7-14 days. They expect to be done with the 4 wells by the second week in February…then the rig goes ??? I heard just north of Holbrook/Chapman units (lots of leases coming up for option)…so not sure when Redhawk will get a rig again…no one knows or no one is talking…I would think Redhawk would do the 2 south units on the Blackshear unit, and then move to the 2 south units on the Pecan pad…hopefully Redhawk can get a rig back first of the year.
You can easily see the rig on the Francis pad when your at the entrance of the Maddox pad..very close…frac water will be coming off of huge reservoir on CR 379. for both pads.
They are already working on the pipeline coming off the Maddox pad to the Copano pipeline I believe they said.
I’ve been pondering the reported difficulties with Parr and Monster and how it MAY relate to KEW and Acaval leases in Fayette County.
As with any sale, the seller tries for the highest price while the buyer tries for the lowest price. If EOG/Redhawk is in negotiations with KEW and Acaval, now would be a bad time for the potential buyer to talk up the potential value.
I still see all those old gas wells where Oakland Road crosses the East Navidad into Colorado County and can’t help but wonder how it all fits together.
FYI - the Nabors #1205 rig in on EOG Gahan A 1H in Gonzales County.
Just north of the DeWitt County line - about mid-way between Smiley and Yorktown
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Can someone (Rock_Man?) explain how seismic surveys work on a non-technical level? In 2012 Seitel came through and did 3D seismic on almost the entire area that we’re mainly discussing.
Does someone hire a seismic survey and therefore own the data? Does the seismic company just do it on their own and anyone who wants the data can buy it? Does anyone use this anymore or have they reverted to ‘closeology’?
Nothing at all ever came of this so I’m just curious.
I will let Rockman chime in on the more technical aspects, but there are basically two kinds of seismic shoots. One, a company shoots seismic for their own knowledge/learnings. Two, a seismic company will conduct a shoot over an area and then subsequently try to sell it to operators in the area who may be interested. If I recall correctly when Seitel did it in the area, it was to sell to companies.
I am very familiar with all aspects of 3D seismic.
Depending on the area, terrain, energy source and a multitude of other issues, acquiring a 3D survey runs between $40,000 to over $100,000 per square mile. This includes permitting, damages, acquisition and processing.
Interpretation will be a separate cost for the work done by the G&G team.
Goals for 3D are predominantly for structure identification and variability plus “seeing” faults (which need to be avoided by any laterals. Structure is important as to keeping any drilled lateral “in target zone”. More info can be gleaned from high quality 3D (e.g. geomechanical info, brittleness vs ductility, facies variation / heterogeneity, etc.).
Seismic companies (e.g. SEI, Seitel, Fairfield, etc.) rarely shoot any 3D using 100% of their own money. Usually one or more O&G groups will underwrite a 3D in return for a proprietary period of time where those underwriters and “work” the data and do whatever leasing they want to do based on the data. After this confidentiality period is over, the 3D contractor will then be able to sell all or part of the 3D to others on a per square mile basis (usually with a minimum number of sq miles).
Side note on 3D and subsurface interpretation - in order to properly image the subsurface in any area, a much larger 3D area needs to be shot and merged together to get the 3D picture.
E.g. to image one square mile of subsurface data, one needs to acquire 5-10 square miles of data.
I could talk a lot more about the whole 3D process and subtleties, but I hope this suffices for now.
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PS note @ 3D sales - a company like Seitel could sell all or parts of any 3D in their library several times over for a much lower cost than that needed for acquisition.
Per square mile prices in the $10,000 to $20,000 range with minimum sq miles for any purchase. And a discount for the more data purchased.