Sorry the numbers got crunched together on previous post…but you can figure it out…
Just curious about why they would lay more large pipeline over a seemingly finished one.
Appreciate any input from you savvy people!
This question is about the Bruhn/Rawlins pad
I heard there would up to 7 lines. There are 4 black poly type and one small poly along with 2 steel transmission lines.
Remember they are still testing everything and 2 of the wells were not drilled but could be re permitted in other directions. Take it as being good news.
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LKranch—any idea where the CR 306 pad rig will go next ? EOG has not started the CR 183 6 well pad yet. Heard a rumor but not confirmed that the rig could be leaving our area again…thanks
Any more activity on the pecan pad? Thanks.
Milton-- have you seen any water or oil trucks going in/out of pecan pad in the last 2 weeks ?
Went by the pecan pad about a week ago or less…and the dozer with the ripper was there, but not moving. Looks like they are going to take a good portion of the pad out.
It made me curious since the new pipe seems to at least 10 inch or more dark green pipe. So much to learn and I guess that’s good since it keeps these eighty yr old brain cell perking. Lol
Mr_ml Pecan pad same as always some body came by this pass week and rolled up 2 reels of the water pipe that was left behind. Did as a well maintenance person about the dozer and loader. He really didn’t known much but said sometimes they make the pad smaller when finished drilling there. Water trucks still getting some days 10 are less loads. It’s a hit are miss on oil truck might miss a day and make it up on next day with 2 loads. It’s any guess were it’s coming from.
Iam like you Kitty just guessing the bigger pipe is for gas oil and water they just sort it out at the new pumping station is my guess they way they don’t need all those trucks running to pad.Also don’t need the tanks and the rest of the junk on location.
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Very common to reduce pad size once drilling in completed. Gives more land back to surface owners and reduces long term damage payments.
Taking water off location via pipeline to disposal site is huge savings - trucking off water will be costing $2-$3+ per barrel (about 150-160 bbls per truck load).
Flow from well being separated on site into gas, oil/condensate and water volumes.
Trucking oil / condensate off location will incur a fee for every BO - $3-$5 depending on the marketing contract.
Less trucking = less pad maintenance and less impact on road network being used.
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Rock Man-- couple of question–
At the well site, before it is put in pipelines, is the separation 1)gas 2) liquids (oil & water), or is it separated 1) gas, 2) oil & condensate, 3) water— then taking 3 pipelines instead of 2 to the EOG gas plant ?
Also, if the water is either separated at the gas plant or comes in separated, would there still be a pickup fee of the water at that location since EOG never drilled or permitted a disposal well at the gas plant location ? thanks
April 2026 Oil numbers are out : this is oil only no gas
Blackshear 179 /day
Parr 178
Reimers 124 about equal to last month
Monster 73 about equal to last month
Francis 118
Friends 610
Harwi 305
Mulinge 480
Now for the Maddox+3 pad/on Migl tract this is NOT per day but total barrels
Bullard 1461 total barrels for month (prob just 1-2 days worth)
Maddox 1591
Holbrook 1612
Chapman 1538
So…we will not know the outcome of these 4 wells until a month from now when the May oil figures come out…however, they all look to be doing the same rate…too early to tell.
$'s paid to mineral owners per barrel:
January $58
February $62
March $89
April $98
I am surprised April is below $100…I was told that the daily oil price was somewhere between an additional $7-$25 per barrel to WTI contract pricing. Looks like EOG is not paying their actual sold price to mineral owners, just futures contract pricing. I will be inquiring about this directly with EOG…not the lawyers…again call them and it cost $$$$
Where exactly do you find these figures.
Is it just a guess on the number of days?
So does it seem like 8 to 900 barrels a day?
Thanks
Full well stream (oil /. condensate, gas and water) goes thru seperator equipment that breaks out gas, water and oil / condensate into individual streams.
Oil / Condensate either goes into tanks or its own dedicated pipeline. Same for the water.
Gas goes into dedicated line that will go to processing plant to strip out NGL’s and residue gas (about 1000 Btu quality-
If water is not going into its own dedicated pipeline a SWD facility, it is picked up by truck (about 150-160 bbls per load) for disposal. Cost will range from $2 to $3 plus per bbl depending on distance to SWD facility and what the disposal company charges
Thanks for the numbers. Note that these volumes do NOT include any NGL’s that are stripped out the gas processing plant.
One will only see those volumes on their revenue payment statements (assuming that NGL’s are being stripped instead of the gas price being upgraded for BTU content).
I will challenge your comment that EOG is not paying minerals owners what they are being paid for the oil. Despite what WTI or any other posted price is, the $$$ paid for any one well / area is based on the oil sales contract that operator has with the operator (in this case, EOG).
Usually this is a formula along the lines of “WTI minus X percent or X dollars”. Plus minus processing / transport fees for the oil (hopefully you have a cost free lease that would knock out these costs).
EOG may also have this oil being priced under a hedging contract that could be less than WTI.
I would ask EOG for a copy of their oil and gas sales contracts (and processing plant contract for NGL’s). Note that many processing plants will take a percentage of the stripped out NGL’s as the “fee” for running gas through processing plant.
Highest percentage I have seen is 50% of the NGL value
Thanks Rock Man for the info !
LKRanch- these numbers come directly from Texas comptrollers office. you can only see total barrels for the month so you divide by 30. So if i said a well was at 178/day it did 5,340 barrels for that month. Now this figure does not count days offline for any reason, and since these 4 wells just started up in april and there is usually a 7 day lag at the minimum…a barrels per day number cannot be calculated yet.
Now some of these wells I have a pretty good guess at when they were down for either repairs, or shutdown due to drilling or fracking on the same pad since I have a little percentage on the wells.
Another thing is that this report is the entire calendar month, while the EOG payouts to mineral owners usually stops on the 26th of the month…and then paid on the 12th of the next month. So if you calculate the barrels per day off your royalty report you can be a little off to the comptroller report.
Looks like part of the separation equipment