Thanks Bob. I havent read through it yet. My world hasnt slowed down enough to smell the roses…
Diane and Ed - Here is the completion report on the Oceana. Section 17 and 8 1N 5W http://imaging.occeweb.com/OG/Well%20Records/1DD2D473.pdf
Here’s an interesting part of the Continental 4th quarter report for 2014. Talks about the SCOOP. CR did beat estimates this time.http://seekingalpha.com/article/2951086-continental-resources-clr-c…
Just an observation: Noticed on our check from Newfield the oil sales were done on the 14th of the month and the check from Continental the oil sales were on the 20th of the same month. Newfield sold the oil for 52.90 for Dec. and six days later Continental sold their oil for $40. and some cents (forgot the cents). Big difference for only six days isn’t it???
Is the hedge price that Newfield gets reflected in the sale price we have on our statements (since we don’t get the hedged price as mineral owners I figured it wouldn’t be on our statements) or did the price of oil just go down that much in 6 days? Anybody?
Linda, other factors can account for price differences besides the obvious…gravity of oil, quality of the oil (Bs&W) etc. but that is a dramatic drop…timing is so important.
S D…I do see that you are a gal not a guy. Sorry about that mistake too!
Hello to everyone! Hope everyone had a great day. This is a question that whoever knows can answer. "What does mean when a well has been temporarily abandoned?
Hutch…as usual you are right. I thought I had looked at both and they were for Dec. but looking back CR’s was for Jan. 20 instead of Dec…I think you told me that CR only holds back for one month and Newfield for two month before but I have a short memory and am a slow learner too…Maybe next month we won’t have to have this same discussion.
Speaking, like S D said, of the gravity of oil, etc. The difference between Newfield’s Branch wells in the Woodford and their Jarred well in the Springer was only about a dollar. The Branch wells got about a dollar more than the Jarred both selling on Dec. 14th. Thanks guys for straightening me out AGAIN!!!
Thanks, soonerpe! This blog is such a great place to learn new things!
Linda, are you sure you are comparing the same month? I believe NF holds 2 months oil and CR only one. On the Plains All American Pipeline price bulletin Dec 15 was $52.50 and Jan 20 was $42.50. If you just got the CR check it was for Jan oil. NF Jan oil will probably be less than Dec. The $2.50 diff could be as S.D. said below a gravity deduct etc.
K Dawn,
Check out Rule # 37-118/Temporarily abandoned wells…
http://www.okc.gov/pw/pdf/c37.pdf
Clint Liles
Diane,
A delay in filing Form 1016 does not delay payment of royalties. The back pressure test is used to set the allowable (how much gas may be produced each month). Gas wells are to be tested within 30 days of first sale. Since many HZ wells are producing large amounts of frac water (the Oceana nearly 5000 BW per day on completion report) the operator may request an extension to file so the test will reflect the ability of the well to produce after more water has been produced. In most cases gas production will increase for a period of time has the frac water is removed.
Forgot when Hubby read about this to report it on here but it was that the Gas Plant down south (guess they were talking about the one that was going in north of Purnell, Ok.) had been either canceled or put on the back burner. Was thinking it was ONG but maybe not. It’s been a couple of weeks since he read it.
Got it; I’m guessing the 30 days to reclaim your well doesn’t come into play here; it only dicusses the oil companies obligations. What say does the well owner have? Does the well owner need to have a say?
Thanks Jerry for the completion report on Oceana! here’s a question for anyone out there that might know… On the Completion Report it states that first production was 12/22/2014, which would mean the first royalty payment should arrive by 6/22/2015, (unless the company pays a 12% interest on a late payout) On the report it “respectfully requests” up to 90 days to complete form 1016 (Back Pressure Testing). Does this effect the mineral owner in any way, such as a delay in royalty payment or in any other way?
is anyone able to answer Mark D’s question “Is it common that an extended lateral well with completion numbers of 6,800 mcf a day (could) actually go into production of over 20.7 mcf of gas per day initially?” and “Does the completion report predict anything”?
Hi folks, has anyone heard of sale prices in 2S-4W, Sec. 22? I’ve been offered $6,800 per acre, but can’t find any “comps”
It is encouraging to see so much focus on OK interests by NFX. I am guessing high initial production rates and relatively low transportation cost in SCOOP and Stack are considerations for short-term investor return.