Doesn’t sound good for us then I am afraid
Deborah,
Looks like they need to paint the tanks. I hope you get a good well. Is this spaced on multi -unit? I’m next to you and they are spacing mine on multi - unit. I think some of the areas that are marginal on production maybe spaced multi unit.
Virginia, what are you considering marginal?
Deborah,
It is when they space 2x640 A together making it a 1280A. Then it depends on how many shots (holes) they put into the H casing and the distance under each section that they drill. So if you are in section 27 and it’s spaced with 21, all the people in both section will get something out of the well. If they hit a good well, then they may drill another later after the first well is paid for.
Hope you get a good one as I am next to you.
Corporation Commission shows the well on Section 27,21n,3w was spudded on February 18th.
Virginia, to you, what exactly is a multi-unit? I am really very green on these matters and I have actually been trying to keep up on it myself.
Deborah,
Forgot to read all you emails.
A Marginal well is one that may only produce 25 bbd and take several years to pay for the well. Investors don’t like a long pay out. These wells are several million to drill and really need to be making about 100 bbd in order to pay for themselves.
Ladies,
They are coming back on our farms near Hunter and requesting from the Ok Corp. Commission to increase the density (drill another well) on that section. I guess it is worth drilling another! It is interesting to read the application. It is more interesting to read the report calculating how much oil is left to recover! Here is what one of ours says: OOIP (Original Oil In Place: 13,497 million barrels. Recoverable Oil: (OOIP X RF%) 13,497,000 X 10%=1,349,000 barrels. Recovery Factor From Existing Wells = 13.5%. Remaining Oil To Recover = 1.172 million barrels. I hope they get every drop! Here is where you can search any order: http://imaging.occeweb.com/imaging/OAP.aspx. Just enter the Cause Number in the Case Number blank. There is a lot of info and drawings on where the wells are and where they will be. Just for information, I could not figure why they drilled our well on another farm. They are now doing what they call “Super pads”. They drill several wells from one pad. I knew they were doing that in Alfalfa County but Plymouth told me this was their third one here. Looks strange to see your name on the sign and it doesn’t match the section number. That is why I thought we would have to re-lease the stake was on our place but nothing was happening! Good Luck with your wells!
Yes I am too
Here’s an 2012 article on enhanced oil recovery (EOR) in the Bakken where my friends working for service industry here in Houston say this EOR is working. I’ve been told Devon will ‘for sure’ use EOR waterflooding and/or gas in my area in Payne and think they can improve oil recovery from 25% to about 70%.
http://www.bakkentoday.com/event/article/id/34431/group/Oil/
Martha, Virginia,
Yes when we had the last boom in the 70’s-80’s, I remember them saying that with that new tech. we are gonna get 20% more from what they got in the 40’s. Technology now is deveoping at a much faster pace than then. In other some places in OK they are taking one of the two vert. wells on a quarter to inject the water and producing from the other one. I think that with better seizemograph reports a vertical well would do quite well and make the investment back faster if you know where the pool is and have a good straw. My grandpa told me, when I was little, that there is a fault on one of his farms where the oil comes from way up north and dumps it in a pool underneath. Well 40 years later they just drilled on it and yep, 500 bbls a day with excellent gas. Hope it keeps it up. It’s a good thing they are doing it now with $100+ oil!
M.D., Your grandpa was very wise. There is a fault in my Payne section where oil now channels up out of the Anadarko Basin and strange as it seems this very oil migrated down out of Kansas and filled the Anadarko basin millions of years ago. North central OK seems to be on the edges of the Anadarko Basin, but companies are finding that some basins are more contiguous than they once believed, because there are now enough wells being drilled that if you draw a line on a map to connect them you will find many of the basins are connected also.
M D,
Hope you get a good well. The reason they drill so may wells in one pad is because of the cost of making these pads. It take a lot of ground work just to get the pads level, then hauling rocks, etc.
On top of that in order to get the full section, they have to be so many feet away from the section line in order to make the curve and get into the H. shale they want to produce.
I’m sure their are always going to be lots of oil in the ground that we can’t get. Look back to 1930’s. Lots of wells were drilled and some are still stripping on. Because of the new drilling methods, frack, etc. they are able to produce shale that couldn’t be produce back them. So, we are having another oil boom.
Garfield: Longfellow Energy LP; Weber No. 24-M4H Well; NW1/4 NE1/4 NE1/4 NE1/4 (SL) of 24-20N-06W; 581 barrels oil per day, 585,000 cu-ft gas per day TD 11,050.
Thanks, Ron.That is good news.I have minerals SE of there, leased by Chaparral, so maybe that will be their next stop!
Bob
Garfield: Chaparral Energy LLC; Dieterich No. 2MH-10 Well; S1/2 S1/2 S1/2 SE1/4 (SL) of 10-21N-06W; 632.79 barrels oil per day, 2,158,000 cu-ft gas per day; TD 11,040.
Wicklund Petroleum Corp.; Hermenski No. 1-16H Well; SW1/4 SE1/4 SW1/4 SE1/4 (SL) of 16-23N-04W; 127 barrels oil per day, 500,000 cu-ft gas per day; TD 10,105.
Still waiting impatiently, ha, section 27,21n,3w. I’ve heard that horizontal wells don’t take long to drill, we will see?
Deborah, sales of oil are public record. I am not expert in the search of this information in Oklahoma but someone should be able to tell you how to search for it.
Thanks for the information Ron, I guess I am really just watching too closely for so small of a percentage in the below well.
I had followed a little on the horizontal wells, and saw how quickly they were up and gone, but I had nothing to compare on a multi-unit well.