Replies to This Discussion

Permalink Reply by VSC DeSoto South on February 21, 2012 at 3:32

I would like to know the same information. I am interested in the sister well. Rocking G Farms 31H. 31H was shut down for a few weeks late summer for technical work then it came back on  line.

Permalink Reply by Larry G Smith P.E. on May 26, 2012 at 14:04

I have noticed the same drop in production but feel that is is due to the choking of the well due to the drop in price the last several month. No use producing the gas with the price so low. Hold it back, it will be there when the gas goes up. That has not bothered me, no use giving the gas away.

Permalink Reply by Crunchy on August 17, 2012 at 14:05

I don't have any info on Rocking G, but Lonnie Welch that is a section up from that has been shut down to rework. Who knows when it will come back on line. I think Swepi is pulling back to get prices up. I don't mind it. Don't want to give the stuff away!

Permalink Reply by Clarence O. McCraw on September 7, 2012 at 6:44

Same thing for the Bedsole 1, in 6-10-12, IP was 17 mmcf/day, but as of Jan. 2012, it was cut back to 9 mmcf/day. I am of the same opinion that the production was cut back until gas prices increased.

Permalink Reply by Ben on October 10, 2012 at 4:55

These are interesting questions and the answers may vary on a case by case basis.  The question is fairly posed, whether the published completion chokes can be changed out from time to time w/o disclosure to DNR/Conservation because they are under their allowable, and then, if that's possible, are they actually doing it.  This would be a question for one of the company's landmen or engineers. We have many interests in many units in the Haynesville and the cumulative production figures are across the board.  We're finding a disturbing trend with wells being permitted and never drilled, and also with really old Scout tickets with dated information for some Chesapeake alternate unit wells implying perhaps that Chesapeake has not completed the well for financial or gas price reasons.

Anybody experiencing any of this?

Permalink Reply by Skip Peel - Mineral Consultant on October 10, 2012 at 7:49

Choke settings are reported along with associated data for each well test.  Using S/N 240586, here is an example.  The IP (Initial Production) data comes from the SDM2G test.  The DT-1 tests are required semi-annual tests.  A reading and report every six months doesn't answer how the well is produced on a daily basis in between tests but it can give some idea of whether production changes are decline related or choke related.  It is also helpful to look at the surrounding wells to see number and date completed.  Local gathering systems have finite capacities and some wells may need to be choked back as newer ones are connected to the system.  In this case the well may have been choked to 15/64ths. in Sept. 2011 to allow for new production and then opened up to 17/64ths. in February, 2012 as total system production declined to the point where SWEPI could open the well up a little.  That's merely a guess on my part and I suspect that all operators manage well and system flows to maintain pressures above the minimum so that they do not incur compression costs.

WELL TESTS

RPT TYP

TEST DATE

RPT DATE

GAS DEL

FLOW PRES

CHOKE

DT-1

02/10/2012

05/01/2012

3782

4144

17

DT-1

09/11/2011

11/01/2011

999

6500

15

SDM2G

06/03/2010

06/03/2010

17431

8519

24

Permalink Reply by Larry G Smith P.E. on October 10, 2012 at 7:51

Well I can not say what is going on but I do know that the production as reported to SONRIS is not constant as I would expect it to be. Maybe dropping a little bit but the drop that I see has to be done by the Producing Company. They can do that by reducing the choke size and/or shutting the well in for a period of time each month. I know that the production for August 2012 was down from 44MMCF in July to 15 MMCF in August. 

Permalink Reply by Larry G Smith P.E. on October 10, 2012 at 7:57

I want to know how often do these companies check the flow meters on the wells. I have customers that are required to test flow meters once a month. It is done by an independent contractor and have a company man and a pipeline rep there to watch the testing.

Permalink Reply by Skip Peel - Mineral Consultant on October 10, 2012 at 8:08

Larry, the meters are checked regularly in the field but are controlled remotely.  Only the well operator and/or gathering system operator would have information regarding choke settings on a day to day basis.  High decline rates and changing choke settings can make it extremely difficult to make sense of monthly production.  The SDM2G test is witnessed by an LOC field inspector.  I've never asked about the DT-1 tests but I doubt that they would be witnessed as the department just doesn't have the man power for that.

Permalink Reply by Ben on October 10, 2012 at 9:05

Thanks, Skip and Larry. You both gave very enlightening answers but I think we can all agree that knowing what's actually going on may be different on a case by case basis or on a company policy basis.  For example, Exco is drilling out its core areas whereas other operators are awaiting better pricing.  Larry, I suspect that the producing company is choking the wells back in some instances, probably more than can be reflected in the DT-1 semi annual test data.

Permalink Reply by Larry G Smith P.E. on December 16, 2012 at 10:21

I was in Pelican this past October for meeting and went by my well location, I have checked the location often and know what the different production equipment  are and have checked casing pressure and well pressure many times. I found something that was not normal this last time I was there. Casing pressure had always been very low with well pressure around 1000#. This past October the gauge on the casing was showing 2,500# and the well pressure was about 250#. Am curious to know WHY. Are they flowing thru the annulus of the well. There were also a couple of mud tanks set fairly close to the well head. One more question, I read where some Judge had given CHK the right to charge royalty owners for the transportation cost. My lease says at Well Head. If you know  this Judges name and location I would love to have that information.

Permalink Reply by Skip Peel - Mineral Consultant on December 16, 2012 at 10:26

http://www.gohaynesvilleshale.com/forum/topics/magnolia-point-miner...

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