Noble: Red Fork (USA) Investments Inc.; Jekyll & Hyde No. 1-14H Well; NW1/4 SW1/4 SE1/4 SE1/4 (SL) of 14-20N-01E; 211 barrels oil per day, 963,000 cu-ft gas per day; TD 9,228.
Red Fork (USA) Investments Inc.; Oxley No. 1-35H Well; SE1/4 SE1/4 SE1/4 SW1/4 (SL) of 35-20N-01W; 198 barrels oil per day, 483,000 cu-ft gas per day; TD 9,744.
Red Fork (USA) Investments Inc.; Whitney No. 1-30H Well; SW1/4 SE1/4 SE1/4 SW1/4 (SL) of 30-20N-01E; 140 barrels oil per day, 570,000 cu-ft gas per day; TD 9,610.
Noble: Devon Energy Production Co. LP; JKL 4-20N-1E No. 1WH Well; NW1/4 NE1/4 NW1/4 NW1/4 (BHL) of 04-20N-01E; 48 barrels oil per day, 15,000 cu-ft gas per day; TD 10,746.
Red Fork (USA) Investments Inc.; Burke No. 1-2H Well; SE1/4 NW1/4 NE1/4 NE1/4 (BHL) of 02-22N-01W; 128 barrels oil per day, 376,000 cu-ft gas per day; TD 9,279.
Red Fork (USA) Investments Inc.; Carnegie No. 1-36H Well; SE1/4 SE1/4 SE1/4 SW1/4 (SL) of 36-20N-01W; 78 barrels oil per day, 278,000 cu-ft gas per day; TD 9,635.
Red Fork (USA) Investments Inc.; Dampier No. 1-1H Well; NE1/4 SW1/4 SE1/4 SE1/4 (BHL) of 01-22N-01W; 377 barrels oil per day, 1,137,000 cu-ft gas per day; TD 9,395.
Red Fork (USA) Investments Inc.; Flinders No. 1-25H Well; SE1/4 SW1/4 SE1/4 SW1/4 (SL) of 24-20N-01E; 351 barrels oil per day, 578,000 cu-ft gas per day; TD 9,684.
Red Fork (USA) Investments Inc.; Franklin No. 1-35H Well; SW1/4 SE1/4 SE1/4 SE1/4 (SL) of 36-23N-01W; 96 barrels oil per day, 23,000 cu-ft gas per day; TD 9,547.
Red Fork (USA) Investments Inc.; Grenache No. 1-2H Well; SW1/4 SE1/4 SE1/4 SE1/4 (BHL) of 02-19N-01E; 36 barrels oil per day, 42,000 cu-ft gas per day; TD 9,695.
Red Fork (USA) Investments Inc.; Hartog No. 1-10H Well; NW1/4 NW1/4 NW1/4 NE1/4 (SL) of 10-22N-01W; 387 barrels oil per day, 239,000 cu-ft gas per day; TD 9,438.
Red Fork (USA) Investments Inc.; Shiraz No. 1-35H Well; SE1/4 SW1/4 SE1/4 SE1/4 (SL) of 35-20N-01E; 86 barrels oil per day, 171,000 cu-ft gas per day; TD 9,453.
Ron, I haven’t found your email, but I will ck again. Thank you for posting the OCC download. I just posted some aritcles on Logan pg. Looks like Miss rock is all across KS and much of North OK probably looks the same. SandRidge and others are going to drill vertical Miss wells and horizontals too, but the horizontals hold the acreage. Miss Chat and Miss Lime are different Miss formations though out and there may be some Misener Hunton too with deeper Woodford and Sylvan.
Ron, Would you please email me the OCC download I need. I have someone who can help me with the download. Thank you so much.
http://www.occeweb.com/Orawebapps/OCCOraWebAppsone.html I replied to your email yesterday . Did you not get it ? Let me know if I can help .
Completion report - Noble: Devon Energy Production Co. LP; JKL 9-20N-1E No. 1WH Well; SW1/4 NE1/4 NE1/4 NE1/4 (SL) of 08-20N-01E; 59 barrels oil per day, 52,000 cu-ft gas per day; TD 10,870.
Noble: Devon Energy Production Co. LP; JKL 5-20N-1E No. 1MH Well; NE1/4 NW1/4 NE1/4 NE1/4 (BHL) of 05-20N-01E; 158 barrels oil per day, 246,000 cu-ft gas per day; TD 10,283.
" Does anybody know about this - it’s been leased but don’t know about when it might be drilled… SE/4 of Section 17-24N-3E, Noble County, Thanks Steve"
Virginia, Is this the HB 1909? http://www.oklegislature.gov/cf_pdf/2011-12%20ENR/hb/hb1909%20enr.pdf
I own a fractional mineral interest in Sec 17 - 21N - 1E in Noble County. It has been leased for some time and I think drilling has been approved but I have not heard in months whether or not plans are progressing. Almost daily I get offers to buy my interests so I am assuming there are still plans to drill. Does anyone have any recent information on drilling plans for this section? Thanks for any help you can provide
Jordan,
Have you heard anything on Section 14-20N-1E regarding payment yet? I know they have 6 months after first distribution which would be december i thought? Do you know anything?
http://imaging.occeweb.com/OG/Well%20Records/1DD0A919.pdfj
John they are drilling all around you Don’t sale . No production information made public yet on your well .One in 28 from 8/2012 to the end of July 2013 did 37,081 BO & 26,409 MCF of gas. One in 21 from 9/2012 to the end of July 2012 did 28,875 BO & 19,270 MCF
14-20n-1e
http://imaging.occeweb.com/OG/Well%20Records/1DD1836D.pdf
From july 11 to the end of July they reported 1,187 BO .
Virginia, Thanks for the OCC info. I’m an investor, so it is good news. I’ve got to study up some more on the pluses and minuses of our OCC rules on multiunits as compared to other shale states.
Martha McMorries,
Yes the house bill is 1909 or OK statutes 87.6 title 52 wrote about 2011. I believe this is an amending of 52 OS, 2001 section 87.1. Under #16 it give some payment information.
But, I still have some problems with the multiunit wells. If I understand everything like it’s wrote. They can drill a well in section 2 for almost a mile and hold all of section 1, but once it goes into section 10 and it’s only drilled 1000 ft, it will hold the whole section 10, but they will only get a very small portion of the check because they don’t have very many feet.
Virginia, I’m going to call a friend who works at the OCC and make sure I understand the multiunit wells, but I do believe you may be correct. N. Dakota had some similar issues. OCC needs to address these issues as well, but will not do so until minerals owners raise a protest. I will post what OCC claims are the reasons for allowing a whole section to be held by such a small percentage.
Martha M,
I have talked to several friends at OCC and they are aware of the problem, but they aren’t sure how to fix it at least that is what I was told.
My understanding from an investor view was the multiunit give a lot more people the option to invest with smaller bank roll since these well cost so much. I have seen some wells as high as 6 million and a few about 3 million. If a company was to drill two 6 million dollar wells ( 1 per section), that is 12 million upfront. Hopefully they will hit a really good well, yet lots are coming in under the 100 mark, long pay out on them.
But if they can set up the first mile for 6 million, the 2nd mile will be a lot less since the paper work done, pads are made, tanks set, etc. Then as the wells start paying for themselves, they can drill more wells in the same sections. So, for the investor, it’s a great deal. Plus no more bonus for the mineral owners who leases where about to run out.
Sandridge drilled a vertical test well in the marmaton with an IP of 500 BOE/day. Good sign of additional reserves in the area. http://www.fool.com/investing/general/2013/11/20/sandridge-energy-i…
Nick,
Are you sure the hearing was after the well was drilled or was it for different formations? Also, if they want to increase the number of wells drilled on the section it would be a new hearing. I have never heard of a spacing hearing after the well is drilled.
Are they hitting any oil in the Marmaton in that area? I thought most of the wells being drilled in 1 e was in the Miss.