We have some mineral acres in 26-18n-04e and have begun receiving royalties from AEP. I have seen mention of well production declining at the beginning and then going back up. This well reported production of around 9,800 barrels/month in April, 6000 plus in May, 4400 in June, etc. we just received our checks for August: 1895. I’d appreciate any insight into whether this is unusual or just par for the course. Thanks to all of you knowledgeable people who are willing to guide total novices like me. Sharon Monsey
Regarding my previous question concerning the drop in production for the well in 26-18n-04e, I emailed the AEP client service people and received a prompt reply. mechanical trouble shut down the well for 19 days.
One more novice question. We have mineral interests in two wells in 26-18n-04e, the bottom holes of which are in 23-18n-04e. there are separate reports (permit to drill, completion, survey, etc) for the surface hole in 26 and for the bottom hole in 23, for both wells. and some of the numbers are different. If someone could explain the reasons I’d very much appreciate it.
Payne: American Energy - Woodford, LLC; Adam 31-19N-3E No. 1WH Well; SW1/4 SW1/4 SE1/4 SW1/4 (SL) of 30-19N-03E; 349 barrels oil per day, 852,000 cu-ft gas per day; TD 9,961.
Visited Payne county from PA this past weekend to find the well Ethridge No. 36-2 WX. I followed the exhibit “B” map of the drilling request to the Corp Commission and found a pad in section 25 18N 04E which correlates with the map. (The pad has signs for four Ethridge wellls). The horizontal well extends through section 36 18N range 4E and 1 17N 4E (section 1 is where my minerals are). Question: The pad does not have a pump??? It does have tanks and pipes with a loud diesel engine running but no big oil pump. Is it located on another pad? Question: The signs indicate 3 other Ethridge wells but I cannot locate any info on the web about these wells and wonder where it might be??? Thank you
David, http://www.pumpsandsystems.com/topics/pumps/pumps/electric-submersi…
http://imaging.occeweb.com/OG/Well%20Records/1DCF4033.pdf
http://imaging.occeweb.com/OG/Well%20Records/1DD071D3.pdf
http://imaging.occeweb.com/OG/Well%20Records/1DD0B409.pdf
David, When it’s a multilateral completion they can use one electric submersible pump (ESP), but they usually case and cement the main bore and lateral to prevent cement failure caused by ESP pressure draw downs and production is co-mingled. However, there can be several pumps used with a downhole splitter when multi wells are drilled cased, and completed from one well bore, so production can be separated.
Marth thank you so much. Whatever we pay you, it is not enough!!!
I am assuming that the submersible pump is handling all of the holes? Must be a problem on how they keep track of amount of oil per hole if the pad is workimg more than one well. Or is there one submersible per hole? Enjoyed my trip to windy Okla and the almost ghost town that used to be my home.
“LONDON—Global energy demand will dramatically increase over the next 20 years…the International Energy Agency said Wednesday.”
“In its annual World Energy Outlook, the Paris-based energy watchdog forecast that global energy demand will increase 37% by 2040.”
“Crude production from U.S. shale oil fields is only expected to continue rising until the early 2020s and will eventually start to decline.”
“Though demand for natural gas is expected to grow by more than 50% by 2040.”
http://online.wsj.com/articles/global-energy-demand-may-outpace-sup…
Larry, Natural gas is called dry gas and is mostly methane, so it’s aka dry methane gas. NGL is liquids-rich wet gas, which includes ethane, propane, butane and pentane, in addition to the dry methane gas. Ethane is the product that is used to make ethylene at an ethane cracker.
NGL per barrel has reached up to $50 per barrel, but NGL prices have fallen, so that the representative NGL barrel is around $34-39 per barrel. Propane is used as a fuel for home heating, so prices could see a boost due to cold weather. NGL prices tend to correlate to movements in crude oil prices, but NGL price could be helped by higher propane exports in the future.
Can anyone tell me what is happening on the Cedar-Grove well, Sec 28, 20N,R2E. The 6 mos since they did the 1st production test will be up in about 6 days. The Production History shows 2 very small results in May and one in June, nothing since then. Does it mean it is not going to be a producing well or is something else going on. I live in Fla and am at a loss as to what I should be doing or looking for. Thanks
I have mineral rights in S5 t18N R3E (Devon’s Joyce 1 well). When the well was completed in early 2013 the initial production rates were sent to the Tulsa World for publication. The numbers were 222 BPD for oil and 453 MCFPD for gas. I have been receiving royalty checks since spring of last year for oil. With each check there is a form that lists by code what the payment is for. The code for wet gas is 203. To date the payment has been for oil, code 100 and for residual gas code 204. I have received nothing for wet gas which I assume is natural gas. Initial production of 453 MCFPD sounds pretty good to me. I called Devon a number of months and asked the same question and was told I was receiving payment for gas. Apparently I don’t understand the numbers or the codes. Martha, can you answer my question?
Here’s a 2012 EIA report on Natural Gas Liquids (NGL’s). Note: the demand/supply are not current.
http://www.eia.gov/conference/ngl_virtual/EIA-NGL_workshop-Anne-Kel…
Sandra
I have mineral rights in a couple of sections north of yours. It took Devon 6 months to get the checks moving. Production reports were behind too. I contacted their mineral rights owners support line to get current info. They have always gotten back after a few days. The number 405-228-4800 opt 4. Lori Graham is who got back to me. She was in charge of Division Orders for that area.
Send some of your warm weather our way.
Good Luck.
Thanks for the info Phillip I will give Devon a call and see what it going on.
Has anyone seen a Completion Report for AE well named Yost 8-18N-1E 1MH? The location is 09-18N-01E. Our lease is in Sec 8 which is being drilled from 09. The Spud date was October 9th. Still may be too early for the report. We are anxious to hear production #'s. Thank you.
24-19N-2E, anybody know if anything is going on here?
I went to check out the section where my mineral rights are located. I found a well that had 4 tanks and the company was flaring the well. I believe this is in section 31-18N-3E. However I can’t find any info on this American eagle energy well. I still haven’t heard from AE about a pooling choice. It was supposed to be on the docket October 7th. I’m in the 5th week waiting for info. Is the 640 spacing per section or can it cross over to other sections in regards to spacing orders?
Thank you Martha!!! Does the pooling order come after the well?? They were supposed to have had a hearing on October 7th. I haven’t seen anything since. How long till the completion report?
G Win, The well in 31-18N-03E is a horizontal Woodford well and was spud Sept. 2, 2014, The OCC has not yet posted the completion report. AEP should send your first royalty production check 6 months from the date of first sell of production which will be noted on the completion report.
MCLAIN 31-18N-3E 1WH http://imaging.occeweb.com/OG/Well%20Records/1DD26E23.pdf