You’re on the ball! I check multiple times a day but you beat me to it. A few interesting notes, they’re back building the lateral so they’ll have ~10,500’ of completed lateral. Also, as noted above about unleased mineral owners, there’s a 54 acre tract within the unit that they have deemed unleased, so they will be either carrying that unleased interest or trying to lease them before the well comes online. So, a little over 4% of the unit.
I just have to say it. Monster Rock Unit sounds like it was chosen by some Junior High boys. On the other hand it makes you think that it has to be like TOTALLY AWESOME! I’m hoping that they’re right.
But seriously folks, I found out more than I ever wanted to know about a holdout tract including court cases but the bottom line is that if the wellbore doesn’t go through there it’s only a minor annoyance. Onward.
I can tell you first hand that drilling through a holdout tract is a massive pain. Had to do it several times early in my career. Basically, you can drill through the tract but you have a no perf zone, so you basically don’t complete X number of feet in the middle of your lateral and have to abide by the required field rules, etc etc. Big ol’ pain in the butt.
The holdout tract is not in the horizontal track of the first well of this unit. I am sure EOG/Redhawk will not drill under it until it gets resolved. These units will only receive 3-4 wells per unit..The Austin chalk wells will have 1000 feet between them….and since they are doing 30+ units, they will have plenty to drill out…which at this time is not scheduled to happen until 2027…they should have 1 well per unit though by this time. I believe it’s also stated in the second quarter results for EOG about the HUGE commitment they have made to buyers on Nat Gas starting in 2027. EOG is saying it will take all of their “plays” to fulfill this. That is why fingers are crossed that this Eastern Eagleford area will bring in extraordinary amounts of Gas…..
New FSNN report from someone in the MONSTER Rock Unit verifying that they plan to drill the other well in the opposite direction while they’re there.
Yeah, it is also different when you create a pooled unit. I was referring to when you’re drilling lease based wells. But in any event, this is all helpful information, thank you!
I’m curious. Maybe one of y’all can clear this up. Go to the MONSTER Rock W-1 page on the RRC website and look at the Rev1 of the plat. Any thoughts as to why these four tracts deserve a plat revision. The acreage is the same on both versions.
The “Reimers” unit has been permitted by Redhawk. This is the unit on the NW portion of the Pecan farm pad. The unit does enter Fayette county and includes St. John’s church.
Excellent! Thanks for the info. I still can’t see it on the RRC site as of now but sure waiting to see it for sure.
You’ve got elite access, mine doesn’t show that unit yet!
Re Reimers: Interesting plat, and I don’t mean the information itself. Apparently contracted with a different surveyor? Hopefully a revised version will be released later. Seems like no big surprises otherwise.
Not uncommon at all to have several surveying companies lined up, purely comes down to availability and the quality of what they put together. Some stink….
Permit is available on RRC website. Be sure you search under submitted date range to see the filings. Permit is still listed as mapping and so will not appear under the approved date range.
Rig 1209 is coming down from the Parr unit…thought they would permit and drill the 2 units south from the same pad…but looks like no. Where is the rig going ? North to Pecan farm or south to Francis pad ? ? I guess we will know in a couple of days..FYI–Blackshear is shutdown again….
My guess is the rig will move to the Francis pad, giving them a chance to frac and test the Parr Unit before moving up to the Pecan Farm pad. But I guess we will see.
Moving rig off of Parr and it’s parts are heading west down FM 532…then turning left onto FM 1295 going south….so it’s either Francis pad or back to Gonzales…thinking its Francis…I guess they are waiting for Parr results before going to Pecan farm, although they already have well logs for Parr…I guess that is why they also did not do the 2 units south of Blackshear/Parr (off Blackshear pad)……looks like we will have a wait…if they do all 3 wells on Francis pad the rig will not be free until December. Still holding out on an extra rig but I heard it was nixed. I should find out some Parr info soon….they were hoping more volumes of Gas as they went east. Also still up in the air if Blackshear well #2 OR most probably I heard unit south of it will be a 3 mile lateral west instead of 2 miles..heard it also depends on Parr but not sure why….
Production numbers
Blackshear
1408 bopd June 12 days 4.7 million cf gas/day
616 bopd July 2.2 million cf gas
first 30 day IP would be about 1000 bopd +gas
Francis
1630 bopd Feb (20 days) 6.2 million cf gas/day
1064 bopd march 5.8 million gas First 30 day IP around 1400 bopd +gas
571 bopd april 3.4 million cf gas
531 bopd may 3.2 million cf gas
440 bopd june 2.9 million gas
348 bopd july 2.4 million gas
FINN unit (south of shiner)
365 bopd may 5.9 million cf gas/day
173 bopd june
194 bopd july
They did 2 Finn units, but numbers were low compared to the others so they concentrated on areas east. As you can see by the numbers Francis is doing a lot better than Blackshear. I was told EOG thought Blackshear was actually going to have a much higher gas rate, and a little lower oil rate…but they are “ok” with it.
Now what I heard today….Parr unit…was told wells logs were “disappointing”, and “not what they had expected”. That is all I got.
I see that the RRC GIS map viewer now shows the MONSTER/Reimers wellbores and they’ve almost exactly 180 out from each other.
Back on 6/21 Rock_Man posted an interesting map with some information about the Tonkawa well in far north Colorado County. Depending on how Blackshear, Reimers, et al turn out it will be interesting to see if they go further NE toward Tonkawa or not. The vast majority of leases in SE Fayette are in Crier, Taylor, Bell and Bostick surveys.
From a totally uninformed standpoint, the disappointing Parr well logs would indicate that maybe NW is better than SE, that is Reimers>Monster?
Regardless, this is a great novel and as always I look forward to the next exciting chapter.
Although the “trend” almost definitely extends to the NE and the Tonkawa 1H well, the complex heterogeneity of the target interval along this trend is highly probable.
Multiple factors can change along this trend - all of which can lead to a bottom-line variability of “Gas in Place for Target Interval” that the horizontal wellbores are being drilled into and frac’d to get maximum gas recoveries.
Combine this with gas prices and economics as well as gas pipeline take away capability and midstream gathering costs and you get a complicated matrix that is being analyzed for each drilling location.
Where are you finding production for this well (if you don’t mind me asking)?