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Permalink Reply by jffree1 on June 7, 2019 at 2:20

They have not. The permit for the #2H expired in January. The #2HB permit is still open until April next year. They have been, until May, concentrating on Angelina Co., with six rigs, but they have recently moved two rigs to Nacogdoches Co., dropped two completely and are now only running two in Angelina. With multiple wells on all of their units in San Augustine Co. they are not under any pressure to drill here at the moment.

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Permalink Reply by James L. Williams on June 7, 2019 at 2:33

Thanks. I appreciate your information.

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Permalink Reply by jffree1 on June 7, 2019 at 9:07

Happy to help.

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Permalink Reply by James L. Williams on June 7, 2019 at 9:28

Have you checked the performance of the Koala Unit wells? I'm amazed at how much better they are than the original wells around Denning like Freeman Farms and McKinney, even taking into account the longer laterals. I gather they used three times as much proppant per foot than was used in the original wells, and maybe that accounts for the improvement. 

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Permalink Reply by jffree1 on June 8, 2019 at 5:04

Yes, I have production figures on all of them. It's not just the lateral length and amount of proppant but a combination of those factors along with shorter stages, more perfs, etc... Those two early wells you named were EOG wells drilled in 2010 and were probably 2nd generation well design. The very first ones were doing good to be 4,000' with a handful of really long stages.

Freeman Farms (2010) is 5,376' with 19 stages for an avg. of ~293' per stage. Very few operators down here ever say, anymore, how many stages they are using but it's pretty safe to say that they are a good bit shorter/more numerous now. Aethon is the only one who will put the number of stages on a G-1 report. BP & XTO never do.

On Columbus #2HR, they put 47 stages in a 7,078' producing interval for an avg of ~150' per stage. I'd suspect that that is fairly common with all operators.

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Permalink Reply by James L. Williams on June 8, 2019 at 8:54

Thanks, I appreciate the information. I suspected that operators were using more stages now as well as more sand and water. I took a look at production from the Columbus #2HR well and it looked to be a good one. Occasionally I look at completion reports in west San Augustine County (I was born in Denning) and XTO lists a lot of their wells as shut-in and don't give an IP. Is that just my imagination or is there a rationale for that practice?

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Permalink Reply by jffree1 on June 8, 2019 at 14:50

They never turn in an IP report until they have a Lease ID # for the well. They turn in a G-1 "Well Record Only" (G-1 report with no IP data) once the well is drilled. It will have all the depth, formations record, casing & cement info needed for the Lease ID to be issued. Then they frac, if that hasn't been done already, and turn them to sales. Technically "shut-in" but may not even be perfed yet so incapable of producing at that point.

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