The leasing is usually the first step. The permit is usually the final step. They may have a deal with Triad on what is HBP.
It is hard to say what they are doing. The have leased a bit recently in the county. However 95% of Apache operations have been on the far west part of the state, Beckham, Roger Mills, and Ellis.
The 20,000ft. sounds like TOTAL depth, vertical + horizontal.
Rick, my lease is with DC Cotton and it most likely shows as Rhonda Wood. Apparently they are one and the same.
Rhonda,
Your lease started in 12/2008. It was for 3 years with a 2 year option. They must have exercised the 2 year option. They started drilling in 12/2012, and started producing about March. Had there been a depth clause (I glanced and did not see one) the lease would have expired in 12/2013 and only held formations not dropped by the depth clause. With the usually depth clause it would have held formations from the ground to the lowest depth producing. No completion report is on file but it looks like the Springer @10100ā. From what I can tell there are about 16 formations in that area. The pooling order listed the following:
Deese
Hoxbar
Marrow
Springer
Upper Dornick Hills
So a conventional lease with a depth clause would have left the Viola and Woodford and possible deeper formations open, but not until the expiration of the lease in Dec 2013. A lack of a depth clause holds everything as long as that well (or subsequent wells are producing.
Someone who was pooled would only see those 5 formations listed above held by production. (it is also possible some of those end up getting released). Other formations could have been leased to someone else immediately. One of the big advantages I see is the future ability to have different leases/negotiations in later years on both above and below formations as production methods change. Who knows what could be produced from those upper zones.
Apache cannot get a well started by December so you would have had an opportunity to lease it again.
Saw where the Woodford in some of the SCOOP areas is as shallow as 8,000 to 10,000 ft. deep but believe it said it was not as thick there as further south.
So, if we currently have a lease with Triad on the 08-02N-03W, we wonāt see one from Apache, correct?
Rick, you are right, we didnāt sign a lease, I mis-spoke! Guess Iām thinking a pooling order has the same effect as a lease?
So since we didnāt sign anything, lease or pooling order, how long are we under that pooling order?
And are you HBP the same under a pooling order as under a lease?
Thank you Rick. So, thatās one of the many reasons why one wants to ensure there is a depth clause, correct? I donāt normally get too involved in that part of it but from all my reading here, I will certainly pay closer attention in the future.
Rick, thanks for that clear explanation. So now I have to ask what happens after the pooling order is expired? Do they keep paying royalties[ into a suspense act]? And when a year or so afterwards the person finally contacts the co.-do they ask you to sign a lease? With the same terms as you had under the pooling? What are your options at that point?
I think the difference according to people on here is that when you sign a pooling order you usually get more money and you donāt tie up your royalty up for as long of a period. I believe they have a year to drill and if they donāt they have to release it for you to lease again. If thatās not right Iām sure someone will say so.
Pamela,
The pooling order expired 1 year after it was issued. (Usual is 180 days). You could have leased the remaining zones while it was under the pooling order. You would just need to be careful about how you do it.
Read my last post on your HBP question.
Linda,
You are right but that is only a small part of it.
And you MAY not get more money out of the pooling order. There are some methods of getting paid better bonus $$ out of a lease than the pooling order brings. 
And in some cases you might get a higher RI out of a lease than the pooling order offers. I did that recently. Hopefully weāll see how my decision worked out in about 6-8 months.
Pamela,
You have an active well now. You should start getting paid soon on it. Most of the time they are 5-7 months behind on the first payment. Then they should be paying within 2 months. No lease is required on that well. You should see a division order right before payment, but there is no requirement that it happens. It is pretty rare not to have one though.
Linda, I think you are right but itās bound to happen, with so much fracing going on there can sometimes be disturbance in nearby wells. Iām sure Don or Martha could elaborate on this.
OK. Iāll get this PDH right out to Triad so we can start getting paid. Then we can work on getting this lease with Apache right, if we decide to do that rather than wait to be pooled. Not sure if weāre up to it, but hey! Gotta get our feet wet sometime, right? 
If I understand you correctly, we need to make sure Apache is going to be going deeper than where Triad is going [Springer Sand]?
Can you possibly explain to me how they can have 40 acre spacing for oil and 640 acre spacing for gas in the same lease? Thanks.
Linda. Whitt 1H-25 gas production has been running about 1100 mcfd, no info on oil.
Linda,Hutch
The Whitt produced 756 mcfpd of G ,165 bpd of N, and 85 bopd in April.
Whitt 2013 gas production per OCC:
Some old report of when the Whitt came in said it was making 50% oil. Wonder what happen there?