any word on Slawson’s spud date in 7-17N-3W?
the bull dozier coming out ,nextn week 17n-3w,s20
Virginia I don’t think I’m answering your question ,if I can . I have been told that when they drill more then one well per pad or section to picture a pack of hot dogs when thinking about how they want the laterals to run to drain the shale formation and that it will take several laterals per section to drain the shale formation. Some shale formations will need an upper and lower Lateral to drain the formation . Are you talking about a certain tract I might look up and see what is going on ?
I was trying to add what types of fracking is available. I have heard that a company has been able to frack as far away as 1/4 miles in the right kind of shale. I don’t have proof of this, but they are using a lot of different types nowadays and it’s going future. Also, some of it bad for our animals. It’s the same thing that is in spay and I can’t think of it’s name, but I know we have to buy it with our licenses.
I have noticed a couple of instances in 17N 3W where Permit to Drill have been issued where they start at the edge of a section and go across the road completing at the far side of the next section. SEE API 08324041 and API 08324056. Does anybody understand this? Most stay within a 640 acre Section.
Ron,
When you are talking about Multiunit Horizontal wells, it’s still my understand they are still spaced on 640 and not on 1280. Am I wrong on this. I understand that the well only pays to the people who are under the 640 well even if it’s going in two different direction.
Also, you may be able to answer this for me. I understand that the Miss. runs east and west and that is why the wells run north and south. So, if you wanted to put a well down and have it run east and west in the Miss or Cleveland or Wilcox, would it do any good?
Yes on the section B
Ron,
My last question.
Lets say, you want to drill a Miss. and you go to the north side of the property and drill south. If I’m not mistaking, the Miss runs east and west, so you have a greater change of hitting a good well.
Now, you have a lease on 2 farms but they are east and west of each other in the section. You get an exception on spacing for 320 A, so you drill. The well is drilled from the west property (160) to the east property (160). I have been told that only a few sands could produce in this kind of a well. Yet I see 4 wells in 1 pad, I assume they are going 4 different direction.
sw 1/4
permit but no spud on 7-17n-3w
ronald here is one for you
http://www.dailymail.co.uk/news/article-2228110/Irish-company-U-S-O…
ADDITIVE TYPE DESCRIPTION OF PURPOSE EXAMPLES OF CHEMICALS Proppant “Props” open fractures and allows gas / fluids to flow more freely to the well bore. Sand [Sintered bauxite; zirconium oxide; ceramic beads] Acid Cleans up perforation intervals of cement and drilling mud prior to fracturing fluid injection, and provides accessible path to formation. Hydrochloric acid (HCl, 3% to 28%) or muriatic acid Breaker Reduces the viscosity of the fluid in order to release proppant into fractures and enhance the recovery of the fracturing fluid. Peroxydisulfates Bactericide / Biocide Inhibits growth of organisms that could produce gases (particularly hydrogen sulfide) that could contaminate methane gas. Also prevents the growth of bacteria which can reduce the ability of the fluid to carry proppant into the fractures. Gluteraldehyde; 2-Bromo-2-nitro-1,2-propanediol Buffer / pH Adjusting Agent Adjusts and controls the pH of the fluid in order to maximize the effectiveness of other additives such as crosslinkers. Sodium or potassium carbonate; acetic acid Clay Stabilizer / Control Prevents swelling and migration of formation clays which could block pore spaces thereby reducing permeability. Salts (e.g., tetramethyl ammonium chloride) [Potassium chloride] Corrosion Inhibitor Reduces rust formation on steel tubing, well casings, tools, and tanks (used only in fracturing fluids that contain acid). Methanol; ammonium bisulfate for Oxygen Scavengers Crosslinker The fluid viscosity is increased using phosphate esters combined with metals. The metals are referred to as crosslinking agents. The increased fracturing fluid viscosity allows the fluid to carry more proppant into the fractures. Potassium hydroxide; borate salts Friction Reducer Allows fracture fluids to be injected at optimum rates and pressures by minimizing friction. Sodium acrylate-acrylamide copolymer; polyacrylamide (PAM); petroleum distillates Gelling Agent Increases fracturing fluid viscosity, allowing the fluid to carry more proppant into the fractures. Guar gum; petroleum distillate Iron Control Prevents the precipitation of carbonates and sulfates (calcium carbonate, calcium sulfate, barium sulfate) which could plug off the formation. Ammonium chloride; ethylene glycol; polyacrylate Solvent Additive which is soluble in oil, water & acid-based treatment fluids which is used to control the wettability of contact surfaces or to prevent or break emulsions. Various aromatic hydrocarbons Surfactant Reduces fracturing fluid surface tension thereby aiding fluid recovery. Methanol; isopropanol; ethoxylated alcohol
At what point in the process do leaseholders become aware of what is happening?
Spacing, permitting,drilling, completion,production.
How do the leaseholders learn about it?
My impression is: Not until production time when they receive a Production Agreement seeking a signature associated with the amount of their acreage.
I do not know what a Division Order is.
I found a document in my Mother’s stuff from 1997.
The Heading is “Voluntary Production Unit Agreement”.
It lists all the Formation levels.
Then the Owners, Acres, Interest. In this instance, the acres were 160 and the Interest added up to 100%.
Harley, a Division Order sets forth the proportional ownership in produced hydrocarbons, including crude oil, natural gas, and NGL’s. More often than not, a single well or lease will have multiple owners. It’s not uncommon to have hundreds of parties owning an interest in a single well. A Division Order is generally received by a mineral rights owner through the mail within 3 to 4 months after well completion.
Thanx
Ron McdK,I know a couple chorus girls in Vegas so I will get my expense pad out and go check this out. 
My only concern, is being
a Scot of the Arbuthnot Clan, I know better than to believe everything my friends on the Emerald Isle tell me.
17 Hrs. ago db said something about a dozier coming out of Sec. 20. Then immediatly
17 Hrs. ago, db posted that a dozier was coming out of Sec. 20. Then immediatly, he added "SW 1/4’. Does all of that go together and the dozier was leaving Sec. 20 from the SW 1/4? My interest is in the North 1/2 section and thats close enough for me.
17 Hrs. ago, db posted that a dozier was leaving Sec. 20. Then immediatly he added “SW 1/4”. Does all of that go together and he means the dozier was leaving Sec. 20 from the “SW 1/4”? My interest is in the North 1/2 section and thats close enough for me.
Claude, this is the last one
20 17n 3w///location s/well site ,work
Maybe a response to “does that mean beginning or ending something?” S being South maybe? Hence, S(outh) well site, to work?" I dunno. It also said “Next week…” I plan on sleeping all weekend…LOL
Vern, The Osage Presentation clarifies a lot. Thanks so much.Looks like about half of the 2013 wells are pinned down. Is that what you see?
Also thanks for Division Order explanation.
I have another IWIK [I wish I knew], I am located in NW/4, 9-17N-3W and leased to Devon. Cousins did too. About 80 acres total. Osage has the rest of the Section.
What is the impact of Devon leases, if any?
So far, I think, there are pads in SW/4 of 9, SE/4 of 8 and SW/4 of 3. All could reach under Section 9.
Who sleeps these days?
Everyone leased or unleased should get notice of any spacing or location exception that may be filed . Pooling info would go to unleased owners. Daily drilling reports, Completion & production information before the checks come out would go to Working Interest Owners.