Does anyone know if you can view what "major" work has been done on a well? Is a permit or a report required if they do something significant to improve the production, such as a refrac? Or install downhole lift equipment or a compressor? Thinking primarily of Louisiana but Texas as well. Every once in awhile you see a well that has a production spike and you don't know why. Can you obtain this info via the state databases? If so, how?
In a SONRIS well file, scroll all the way to the bottom to the section, Work Permits. When a well is re-fracked, there will be an entry. Here is an example. For Texas, I suggest you ask Julie, jffree1.
|REFERENCE NUMBER||APPLICATION DATE||EXPIRATION DATE||WORK PERMIT TYPE||WORK PERMIT STATUS||WORK PERMIT STATUS_DATE||TOTAL DEPTH||WORK_PERFORMED||DOCUMENTATION RECEIPT DATE||TEST SAND||WORK DESCRIPTION|
|314-21-3-13-14||05/05/2021||05/04/2022||HYDRAULIC FRACTURE STIMULATION||APPROVED||05/05/2021||16381||Y||07/14/2022||MIRU WOR & PULL TBG AND CLEANOUT VSG TO 16,381' PBTD, RUN 3,25" LINER TO 16, 370', CEMENT LINER IN PLACE AND BACKOFF 100' BOVE TOC, PERF LINER AND FRFAC HAYNESVILLE FROM 11,652' TO 16,301' WITH 31 STAGES|
A timely question Hale, thx for posting it as I've been trying to determine what occurred w/ the Talbert 10-14-16 H1 since April of this yr. w/ the well having been drilled back in 2011.
MB, appears to me that two new Paloma CUL HA wells came online. There were two Diversified CV wells and one Paloma HA wells before that.
I saw that earlier today Hale but not being in the industry I'm still UNC on how the two PNG CUL's impacted the older Talbert's production as they def. stimulated it, is that a normal occurrence?
I think it can go either way, a child well can negatively or positively affect the parent well production. Hopefully, operators have figured this out these days such that the negative is less likely to occur. I have no idea if they actually did anything to the parent well from an operations workover standpoint. If you know that the parent well increased production, hopefully, it benefited from the nearby CUL well being fracked.
If you own an interest in this unit, you are privy to the individual well production through your check stub; the general public is not, because the unit production is comingled, at least from a reporting standpoint. Except that there is a recent thread here on how to determine the CUL well production, so, in certain instances, you can use some arithmetic to figure out the parent well production if there is only one. If two or more, I guess not.
Whenever you see the initial production report for a group of new wells in a unit, check the unit well (first unit well drilled) for a Well Permit to refrac. It is clear from my work that Aethon regularly re-fracs the unit well when they complete new alternate unit wells in the same section. Makes sense. While you have the completion crew on site to frac the new wells, why not re-frac the older well. Particularly when you know it was under stimulated proppant wise.
TY you Hale & yes beside's my WI/RI in the Talbert I have the same in the PNG CULs. I look @ the production #'s monthly when entering the data into my spreadsheets just didn't know the recent increased production w/ the Talbert was due to the fracing that occurred w/ the child (Graham) wells.
It is common for "parent" wells to lose production, not gain production, when "child" wells are drilled. If there is communication between the parent and child frac cylinders, it tends to result in a pressure drop in the parent well.