Only 1 today hauling crude oil all the rest hauling water at least 20 plus loads per 24 hour period frack water.
Tx RRC production filings run about 2 months behind - Nov 2025 now available.
But don’t be surprised if EOG holds back on reporting these numbers. Pretty typical for many operators
150-160 BO per truckload
The price at Henry Hub is almost twice as much as the temperature at our house. This should make producers of gassy wells feel pretty good.
Nice but very short term.
This is the latest RRC list I could easily find (2022) and I guess I meant that if you’re producing that many MCF even a short term spike is pretty meaningful. Since EOG is second on the list, this should provide them with some incentive to drill a few more wells.
Well…it’s gonna get out soon anyway….even though I think if you don’t have anything good to say, don’t say anything at all….it’s gotta be said….don’t kill the messenger please…
OIL only—
Monster 41 barrels
Reimers 181 barrels
This is not BOPD…this is the grand total for December.
I believe flowback begun around 12/10, but lets say 12/15 ….and lets say it takes 7 days for the oil delivered to post (this is what I have experienced with EOG),.. then we have 9 days of production here…so divide that number by 9 to get your bopd..
I posted here about 2 months ago that they told me “dismal”. …no idea this is what they meant….There has got to be more…we have to wait a month for January’s numbers to post…..this will show us the true story…..I was thinking these were going to be at least 300 bopd wells (30 day IP)…still low….these must have been down or something….has anyone else heard anything about the production or issues ??
I would not get to worked up about 1st month production - and especially oil. Post frac flowback often takes a lot of time to “clean up” and achieve what may be a stabilized O&G rate.
Some areas in the Spraberry trend in the Permian take 2-3 to achieve stabilized O&G production.
That being said - and with gas prices what they are - daily liquid production needs to be well north of 500 BPD to see these wells as economic and merit more drilling.
I am most certainly not suggesting your source isn’t informed but it wouldn’t do EOG much good to talk about the wells being good if they intended on acquiring additional acreage. Much easier for them to sandbag.
Of course, the wells may indeed not be good, I am just playing a bit of devils advocate (with the hopes it’s not true given where my family’s minerals are!!)
This is from Kelly Hancock State Controller….I am trying to attach the Reimers report…
Scan_0200.pdf (211.5 KB)
Thanks (?) for that information. In looking for anything to cling to I see the Comptroller report shows the API GR as 43 which is really close to being condensate. Makes me wonder (1) how much gas is being produced and (2) if it’s still early in the flowback process.
Still early in the process. Gas rates important but need better consistent prices.
Plus no idea of NGL’s / Btu content of the gas (and we will probably never see that info).
This load was only $55.90 per bbl - poor.
Best to circle back on this whole topic after we see 6-9 months of production (and decline)
Milton– You might be able to help us with this debacle….I know what looked to be a workover rig was sent to the Pecan pad but not sure if it was before or after flowback was started. Do you have any idea ? or how long it was there ?
We also have not received the Nat Gas report…and this could be a saving grace of sorts….if it is really good. I am thinking if they started flowback and identified an (another) issue…sent in the rig to clear it up…we might have a huge difference in production in January.
On my post #729 I mentioned old investor presentations. Not that any of them were successful but here’s a good example:
Also keep in mind that the Acaval leases will begin to expire in May so that should tell the tale if they’re renewed or not.
ML Was told they would start on Dec26 first gas we seen was burning Dec29. Steamers were going good Dec 22. Jan8 rework rig and tall crane to remove part of tree to run tubing. Took about 3 days than another company came in after rework rig moved out than they were here for good 5 days. As of now all the extra equipment left this Thursday. Water tankers are down to 25 a 24hr day and another load of crude oil Thursday. Ask me how I know all this about trucks my game cam doing more than looking at deer 
to cold for water trucks. Hope this helps.
This explains a lot. They were only probably able to get 1-2 truck loads in the books by 12/31. So these numbers for December do not show the true story.
When factoring January’s numbers we will have to figure it as a 3 week month due to all of the down time. We only have to wait about 4 more weeks to get the numbers !!
thanks
I wanted to check some dates with the postings here…on or before12/6 frac was completed on pecan pad, all equipment leaving, 12/15 flowback was in process–not sure what day it started, 12/22 picture posted of steam coming from coolers. Conclusion..same…we are not going to know much until January’s numbers post….
I will sound like a broken record here, but you will need to see several months of production before coming to any conclusions about the viability / economics of this or any other frac’d Hz well.
Suggest you wait until June 2026 numbers are in.
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No knowledge of the wells to north but the mid-county well had a extremely favorable NGL cut. Made the effective price of gas close to $8 p/MCF on residual (dry) cut of $3.18 HH. Add 1000+ bbl of condensate to peak month and a much lower decline rate than traditional EF wells… something to get excited about.
Kenobi and Alfaro units are on track, and I believe they are just starting the second one. Bruhn and Rawlins units have issues with permit. With Rawlins they are having to wait until 2/16 based on legal issues with a 70+ acre tract. Bruhn same issue but they are trying to move the well to the south. EOG will be finished with the first 2 wells by 2/7…but do not want to move the rig…they actually have no pad available by then in this area…so they will probably wait for some of the legal dealings however, the wait could go longer based on the mineral owner.
The Maddox+3 pad units have yet to start the frack process…waiting on gas production facility and pipelines…but should start soon.
Saw a need pad being built on CR 195 and Lavaca river, but this is not EOG.
They are running electric power poles to Blackshear Pad.
Both myself and relatives are in a couple of the EOG pad sites, but from what we were told a month ago and then now…timelines are all over the place.
What is the website to find out what unit Nabors rig #1209 is currently drilling ? I know someone had posted it before …but I can’t find it… thanks !!!
I think it gives spud dates ??