Definitely not the Wanda Ramsey we know and I know a Martha Henson but not the same as yours. They both share their names with some great gals!
OCC well browser is an interesting tool. My first search was for 6-1N-1W in Garvin. I donāt think there is any activity there, but it returns 7 āACā for active wells. All have them have no operator assigned and no documentation under the imaging tab. I presume these are all long abandoned attempts.
While my main goal is to get an accurate picture of what is HBP vs. available for lease, and confirm that weāre receiving royalties where HBP. I also worry that we have old leases where we are not receiving any royalty but the operator will claim to be holding the acreage in hopes of controlling it for a new play. Hoping I can find a good way to have a clear picture and eliminate any confusion on old leases as to whether they are active or not.
Chris,
It is a little more complicated in some instances to tell if something is hbp (held by production). Unfortunately in Garvin County there are leases still holding acreage from the 40ās that people are not being paid on. Especially if the original lease had minerals covering multiple sections on it. You can have one well producing in one section with mineral owners being paid, but the minerals from the next section are held by that lease and you are not being paid on them. Sometimes people sell their minerals after leasing on one of those old leases and the interest is split, yet that original lease still holds the minerals even though you donāt own the part that is producing. I hope that is a little clearer than mudā¦
Sometimes it is very hard to determine, as one well could hold the lease until the 60ās, but before they plug it another well is drilled that will hold it. If in doubt about a certain interest all the old leases need to be looked at and cross referenced with releases from the oil companies. It can be very time consuming.
Rick, Darla & Michael - Thanks for your responses.
Darla, uugh, none of this turns out to be simple does it! And, Iām afraid to say I donāt think I have ever seen a release. Do I need to make sure those are filed? It seems like my first pass at this would be to figure out if there is currently production where I have a mineral interest. If there is, I know it is HBP. If there is not, I need to figure out if a multi-section lease covering it that may be holding it.
Michael, in your example, is there a way you could tell there was production going on under the lease?
Rick, thanks for looking at 6-1N-1W. Do you do this through the OCC well browser of some other resource?
Perhaps my bigger question is what do people typically do to organize family mineral interests when at least some of the records are not well organized?
Is there a straight forward way for me to determine when a mineral interest is held by production? Iāve been trying to organize a set of family interests and then figure out what is/not available to lease. Thanks for any pointers.
Chris,
I donāt see any current production from 6-1N-1W.
Darla, I know what you mean I recently got a $90 check on a well that hadnāt paid a penny since 1992. That paid me up back to 1999, donāt know where the other 7 years went. Obviously my net royalty had a whole bunch of .00000s in it.
Yes, I meant Garvin County.
Thanks
Chris, this may be too simple, but are you receiving royalty payments for a tract of land that is (or was) leased? You can go to the OCC well data browser site and check the location of wells in each section and the status of the wells.
Lynden, thanks, the OCC well browser seems like a good start. I should have said Iām not confident I have checks in all cases so Iām hoping to find another route to a list of what is producing.
Chris, I was able to find the production records (gas only) on the OCC wellbrowse. It was obvious they had continued to produce past the date of my last check but when I called the company the number was no longer in service and I assumed they were out of business. I blew it off because it wasnāt much money and out of the blue I found out they were playing catch-up so they could sell the well to another party. I assume the new company has plans to crank it back up but I still think it will be marginal. Not in any of the hot plays.
Hi. Help. What is Merge # and PUN #. Thanks
I found some gaps in mine but itās only as reliable as the buyers reports.
Darla, Iām confused? I have minerals in 7 3N 3W. Merit has several wells that I receive royalties. Unitized. I am trying to find out if they have all my minerals tied up. The original lease said the had the whole section. Do they just have the minerals where they have wells or do they have it tied up for 1/8. Iām new to this and it is very confusing. This lease was back in 1990.
So what does that mean that Merit has control and they will either drill or lease to someone else? I also have a well that Chesapeake drillers that is shut for safety reasons in that section, If merit has it in the Purdy unit how does Chesapeake have a well? Again new at this and donāt understand.
Karla, If it was a 1990 lease that included the whole section then whatever minerals you have in that section are probably held by that lease. If minerals in other sections were on the lease they would not be held unless they were part of the unitization because of the date of the lease. I would have to look at it to determine for sure. Once you lease your minerals and there has been drilling (unless you have a depth clause) whoever leased your minerals can assign out your lease to anybody that want to and you will not know about it until you receive a division order on a completed well or want to change the spacing. Unless you keep checking at the courthouse for assignments. Good that you have production, bad that it is only at a 1/8. You should be receiving a check on what percent of interest you have in the unit even if they arenāt drilling in your section, which can still add up if you have very many acres.
Tom, it depends on several factors on a lease, but spacings have nothing to do with how much of your minerals are held unless you have a pugh clause. If you had a pugh clause then you are correct that they can only hold what is within the spacing unit of the producing well or unit.
Chris, Yes, that is the best way to look at it. Very good at deciphering my explanation. You are probably not going to find releases on all leases even when they are expired, but the older leases most usually have releases if they are released. In the 70ās and 80ās oil companies became very lax in recording releases. Just one section/tract at a time is the only way to figure them out or hire someone to do the initial work and figuring them out and then take over from there. I know a lot of yours are East of PV and most of those old units shut down in the 80ās, but there are a few scattered wells that are still holding acreage. That is where my families minerals are. Pretty disconcerting when they were making $3,000 a month in the 80ās and now Iām lucky to get $65 every few months, but atleast they arenāt being held under the old 1/8 leases any longer.
On my quest to research whether interests are held by production, a super helpful person at the corporation commission told me about part of the tax site that is new and helps research what production is being reported.
https://www4.oktax.onenet.net/GrossProduction/PublicSearchPUNbyLegaā¦
You can search a couple of ways and it will return a list of matching wells & their status. You can then click on the well and it will show the reported production for the last couple of years in addition to some details about the spacing under the Lease tab.
No idea if this is really new but it is to me and seems very helpful, so passing it along in hopes it is to others.
Wow Chris!!
That is a new one to me!
PUN=Production Unit Number, donāt know about merge.
The easiest way is to search by legal, the resulting screen will give you the PUN which you can click on and get well information.