I’m not an engineer but can coiled tubing set plugs during fracking?
Yes but more likely they’re cleaning out the well after screening out or fishing wireline guns.
Both water lines in the ditches were at max pressure. I didn’t realize how much those lines can expand.
I also saw that truck going down FM 957 as I was coming from Pecan Farm pad. Saw tanker trucks entering Pecan pad and they were watering down the gravel…very dusty…also many other components entering Pecan pad site…to me it looks like they expect a rig soon….however did hear a “rumor” not a confirmed source that after the rig finished the well on Francis pad it is going to Pecan pad, then back to Francis, back to Pecan pad and back to Francis again…something about not bringing all the wells online at once on Francis pad…..again not a confirmed source…to me sounds like a lot of work and expense to be moving that much.
I am right down the street from the Potter’s farm. I am seeing a lot of water trucks and other equipment. I also heard that the Pecan Pad is going to be a little while longer. I am right outside of the Monster Rock unit. Can’t wait.
I have not found a Redhawk permit for the Pecan Pad anywhere (or whatever name they plan to use). Has anyone seen anything for that pad yet? I hope they start mobilizing the rig soon. Seems like a huge waste of money to have those 2 huge cranes on standby.
William1, are you meaning that one of the permits that you attached, (Monster & Reimers) is the permit for the Pecan pad wells? We’ve seen a lot of oil field flatbeds moving materials and equipment to the Pecan Pad. Redhawk has raised up the rig today & it’s visible from 957.
Yes, that’s correct. I drew the units on Google Earth (may not be 100% accurate, but you should get the general idea). Reimers is the NW unit and Monster Rock is the SE unit. Pad site will be in the middle on the Pecan Farm.
I can confirm that the rig is on the Pecan Farm pad. I tried to find a rig number but could not see any signs. I am wondering where this came from… is it one of the three other Eagleford rigs EOG has or is this a “new” one? In 2024 EOG had six rigs in the Eagleford and for 2025 they went down to four… could they have “revived” one to get these to get the other units drilled to hold before options come due? Number of wells in 2024 in Eagleford was 160 and 2025 plan was 120 wells, however they reduced it to 110 late Spring. Also frac crews for Eagleford went from two crews in 2024 to one crew in 2025… however, I can tell you the frac crew doing Parr is not the same as what did Blackshear. Hopefully EOG has stepped up and revived a new rig. If anyone can tell where the rig came from let us know… thanks.
May be the Nabors #1209 rig / 3000 HP. Not sure where it came from.
#1209 was moved from Parr to Francis pad just around 10 days ago or so… I confirmed #1209 was on Francis… sign was up… I think it is too early to be finished already.
Enverus says the rig on the Pecan Farm pad is Nabors 1205.
Here’s hoping that they learned something from any problems they may have encountered with Blackshear and Parr AND they have first-rate drilling and completion people doing the work.
Nabors rig #1205 is one of the 3 Eagleford rigs in Southwest Texas. Four rigs are dedicated to the Eagleford, three in Southwest Texas and the other one in our area, mainly being Gonzales County and the wells around here. Rig #1205 comes from Atascosa County, the county EOG just recently acquired 30,000 acres in. It was on the Clydesdale unit drilling well #7H, and I heard it left abruptly before starting well #8H as previously planned.
So, will it go back after these two Pecan Farm wells are done? EOG needs two rigs here to drill one well in the additional 28 units (if Pecan Farm is proven and does not count Fayette County tracts). Two rigs would have it all done by the end of 2026, which I heard was the timeline. First, I was told this was the plan, to bring one of the three rigs up here, as I mentioned in a post about 2-3 weeks ago; however, then I was told it was nixed. Now all I hear is crickets.
The “rumor” out there now is that EOG had to pull this rig to Pecan Farm so they can look at the well logs (not time to even wait for frac results) ASAP because of the lease “assignment” negotiations, to see if they want them and how much it is worth to them.
Personally, I think they would have just waited to move rig #1209 to Francis after it left Parr and just sent it to Pecan Farm. So, I am thinking this could be “Redhawks” assigned rig, and Atascosa County will be operating with just two rigs for a while since almost all of their acreage is held by production.
Mr_ML: I think you mentioned that EOG leased 38,000 acres in Lavaca County. Let’s estimate another 10,000 in Fayette County for 48,000 in all. It suddenly came through to me (duh) that 1200-acre units are not as much related to geology as to the lease holdings. Forty units. Then with directional drilling, they can hold by production four units, 4,800 acres, from one pad, greatly reducing infrastructure costs.
Ultimately, ten pad sites if everything goes as planned.
They paid at least $700 per acre for the leases, so they’re pot committed for a cool $33 million. You’d think that they’d do one more pad site at a minimum just to get an idea what they paid for.
Out of that 38,000 acres, 10,000 already permitted—four units by Francis, two by Blackshear, and two Pecan Farm average 1,250 acres each, and you get 10,000 acres already. Maps indicated three more pads each drilling four units between Blackshear and Francis. Basically draw a line: CR 194, FM 340 at the curve, and CR 183, unless changes have been made.
I have not “seen,” only heard of plans north of Blackshear, and it can follow up to Pecan Farm, which would be one pad, four units. But then you have quite a bit of acreage to the west going up besides Modern Energy and Baytex. First indication had these be lower/upper Eagle Ford wells going north/south (by FM 1295), but possibly Redhawk can do some 3+ mile laterals if that would work on Atascosa County wells. If that was the case, Redhawk could do laterals going from almost FM 1295 to the west to about FM 957, and then FM 957 to US 77. Then this would be heading to the northeast.
The Fayette County acreage above Pecan Farm units has a definable path to the northeast, two pads, eight units, but they have to get the acreage, which will option January 27. Not expiring but added cost if they have to pay the option, pay KEW, and give KEW a percent on top.
The EOG tracts south and west of the Lavaca River (which was the “rule” of whom Redhawk or EOG leased you) is all EOG, and they are $1,200 per acre options, some coming due March 2026, most in the northern section right below the river, so more money.
Also an interesting FYI—some of the southern units will cross over the Lavaca River where the west side is EOG and east Redhawk. They will share a pad for the four units.
And for those following EOG, you see they never really mention Redhawk by name nor do they show any of the 38,000+ acreage they have leased on any maps or presentations to the public. Still trying to keep it on the DL even though who doesn’t know?
EOG could easily joint venture with KEW and have EOG be the operator. That way, they wouldn’t have to buy the leases from KEW. Lots of ways they could work together and likely ultimately will have to in order to optimize the unit configurations, etc., if more wells are planned for northeast into Fayette.
Personally, I think the Reimers and Monster units either make or break the area. If they are bad wells, I think this area is dead forever unless someone targets a new formation. Just my personal opinion though. I will be watching the Reimers unit VERY closely, seeing as our property is just to the northeast.
I am guessing Pecan units will not yield that much oil, but the goal for EOG is gas. They could have pretty good gas that lasts a while. At today’s prices, not very profitable when the well cost $10 million plus. On Blackshear for July, I only got $2.44 per thousand cubic feet (market at $3.15), and then EOG, after cost, got half of this. They are paying 22% royalty. Basically, they are making $1 per thousand cubic feet at best, and they have a lot to pay back—well cost, pipeline cost, leases, etc. The hope is by the end of 2026 natural gas at $5 to $6 per thousand cubic feet, and 2027 $7 to $9 per thousand cubic feet.
It’s all about the amount of natural gas needed to power the new power plants sitting next to the new AI centers around the U.S.
As I had posted before, look at EOG’s second quarter presentation. They have pre-sold natural gas in 2027.