So as the Eagle soars, we see more of a realistic future of production I have always insisted is in our future in Logan County as well, production announced at over 20,000 yes, twenty thousand BOD per net mineral acre. This far exceeds the bestest guesses of most geologists, who miss more than they score. Nothing new, and we should remember that even the very best seismic devices go haywire much of the time.
Ron Von Wilson, Amen! Well stated and I applaud you.
how can I find merge and pun number for branson 26 17n 4w logan co.
Michael, The production number will in the completion report.
http://imaging.occeweb.com/OG/Well%20Records/1DD12BB9.pdf
In this case 083-210514-0-0000
It is a bit early for that one… keep checking it should show some numbers in the next 30-60 days.
Folks it’s just to early to say how much production per acre will come from the Oklahoma Miss/Woodford play in Logan Co. Here’s a current article from SandRidge which states that KS formations are different than OK, but SandRidge still sees opportunity across all of Kansas. http://hosted.ap.org/dynamic/stories/K/KS_KANSAS_OIL_SANDRIDGE_OKOL…
Lisa Where are you and how many acre do you have ?
My own personal opinion, very real, is that we can always find ways to support payment of our medical and surgery procedures. I know anyone and everyone can do this. But I will not sell my mineral rights, thus cheating my kids and grand kids and their kids of any blessings of the earth, that have been handed down to me from my great grandparents and grandparents. This would be absolute betrayel of what my Grandfather wanted for us for generations to come. He went without for all of his life to pass this down to us.
A few minutes ago I spoke with Attorney Ralph Harrison in Kingfisher, OK and he referred me to Attorney Stephen (Steve) McNamara in Tulsa, OK. 918-599-0300 who is right now dealing with a case of “communication” between formations that large horizontal fracs are causing. We mineral owners need to be aware that the possibility of large fracs encountering (called communication) additional formations than the originally intended and OCC allowed formation exists. Also, you need a sophisticated lease to address many future developments, because companies all across KS and OK are just now determining how to encourage future production from shale formations. Even if you have already leased all your minerals you still need to know your legal rights and remedies to all the possibilities and problems that will surely come.
As companies get around to drilling, they are going for deeper horizons than some of the old spacing orders. They are also going to be drilling horizontal wells instead of vertical wells, so the spacing needs to change. Vertical wells at these depths had 80 acre spacing. The horizontal wells need 640 since they are drilling across the whole section (and sometimes two). So they are coming back to the commission and getting the permission to do so. You aren’t sharing with the other section, they are just using one hearing to take care of two sections at one time. Also, Devon has been using one pad and drilling four wells from the pad into four sections, so they are just tidying up and making sure they have spacing orders where those wells will have their bottom holes. Pretty standard practice. 640 is common spacing in this whole area for the Miss Lime, Woodford, Hunton and Silvan.
You often see an Increased Density or Multi-use order, Location Exception order next and then a Pooling order if needed, then drilling permits-all part of the logical process. Looks like there is already a s. 15 well permitted.
how can I find merge and pun number for branson 26 17n 4w logan co. ok
So as the Eagle soars, we see more of a realistic future of production I have always insisted is in our future in Logan County as well, production announced at over 20,000 yes, twenty thousand BOD per net mineral acre. This far exceeds the bestest guesses of most geologists, who miss more than they score. Nothing new, and we should remember that even the very best seismic devices go haywire much of the time.
Show me some documentation on this 20,000 barrels per day, per acre statement! I think it would be hard to find a well that would produce 1000 per acre a day.
Also, I find your statement pretty insulting to the geologist who frequent the board to help others with their expertise. I think an apology is due…
Another question: A few of these have been a bit difficult to sort out. Where the well hole and the lease name are on the same section, the production is pooled? Is that correct?
But what if the Well’s section location is different from the section Lease location? Who gets the Oil & Gas? Which Sections?
I have highlighted those differences in BOLD below.
All of these wells have spudded.
API NUMBER: 083 24154
Horizontal Hole Oil & Gas PERMIT TO DRILL
WELL LOCATION:
Sec: 15 Twp: 19N Rge: 3W County: LOGAN
Lease Name: CHARLEEN 15-19N-3W Well No: 1WH
API NUMBER: 083 24158
Horizontal Hole Oil & Gas PERMIT TO DRILL
WELL LOCATION:
Sec: 15 Twp: 19N Rge: 3W County: LOGAN
Lease Name: CHARLEEN 14-19N-3W Well No: 1MH
API NUMBER: 083 24167
Horizontal Hole Oil & Gas PERMIT TO DRILL
WELL LOCATION:
Sec: 15 Twp: 19N Rge: 3W County: LOGAN
Lease Name: LENA 16-19N-3W Well No: 1WH
API NUMBER: 083 24201
Horizontal Hole Oil & Gas PERMIT TO DRILL
WELL LOCATION:
Sec: 15 Twp: 19N Rge: 3W County: LOGAN
Lease Name: LENA 15-19N-3W Well No: 2MH
oops, I bold-ed it all 
Do you see the difference though? In well location and the lease section location?
Does that even matter? Are sections pooled with other sections???
Thank you M Barnes!
Debra Acord, do you mean 95 mineral acres in Section 36-15N-02W Logan County?
yes i apologize for the type it is 36-15N-02W Logan County
The production is allocated by where the perforations are. I looked these up this morning. Will try to make a sketch for you after a bit.
Yes it does. It took a few times to wrap my head around it…but now it makes perfect sense. Thank you again for taking the time to explain that to me. That really helped me. My next question is …will devon wait until all the units are drilled from those locations before they pay…or will they piece meal payments? Do you have any experience with their practices? Thank you again, AY
Logan: Devon Energy Production Co. LP; Maverick 36-19N-3W No. 1MH Well; SE1/4 SE1/4 SW1/4 SW1/4 (SL) of 36-19N-03W; 41,000 cu-ft gas per day; TD 10,814.
Devon Energy Production Co. LP; Maverick 36-19N-3W No. 2MH Well; SW1/4 SW1/4 SE1/4 SW1/4 (SL) of 36-19N-03W; 9 barrels oil per day, 22,000 cu-ft gas per day; TD 10,773.
Martha, Bobby D was also producer of my own Grandparents vertical in 20-17-3 as I recall back in the 90s, I thik it started in 1980 or so and produced through almost all of the 90’s. Some of us had a lot of questions but I did not have time back then to participate because at the time the production was pretty low. My brother, a Trainmaster for the Frisco RR at Enid back then, and I went out and did a little snooping, but found nothing amiss or out of the ordinary. I wonder today if Bobby has any intention of going it again at this location, and is he able to do this? Lots of old plugged wells are coming again for a Second Coming, with amazing results, even the verticals.