SERIAL

WELL NAME

WELL NUM

ORG ID

FIELD

PARISH

PROD TYPE

SEC

TWN

RGE

EFFECTIVE DATE

API NUM

251932

AUS C RA SUU;CROSBY 10

001

P5184

8744

58

00

010

02S

06W

09/10/2019

17115202360000

 

PRMT DATE

SPUD DATE

STAT DATE

ST CD

09/10/2019

09/10/2019

01

WELL SURFACE COORDINATES

Surface Longitude

Surface Latitude

Lambert X

Lambert Y

Ground Elevation

Zone

Datum

0-0-0

0-0-0

1854779

83393

147

N

NAD-27

WELL SURFACE COORDINATES GENERATED BY DNR

UTMX 83

UTMY 83

LONGITUDE 83

LATITUDE 83

503528.73272131

3417994.6699834

-92.96308341

30.89526444

View GIS

BOTTOM HOLE COORD

EFFECTIVE DATE

END DATE

PLUGBACK TOTAL DEPTH

TRUE VERTICAL DEPTH

MEASURED DEPTH

LAT DEG

LAT MIN

LAT SEC

LONG DEG

LONG MIN

LONG SEC

COORDINATE SOURCE

LAMBERT X

LAMBERT Y

ZONE

COORDINATE SYSTEM

09/10/2019

16200

23000

02

3136160

136624

N

02

09/10/2019

16200

23000

02

1855372

75919

N

01

WELL HISTORY

SERIAL

WELL NAME

WELL NUM

ORG ID

FIELD

ST CD

PT

WELL CLASS

EFF DATE

END DATE

STAT DATE

251932

AUS C RA SUU;CROSBY 10

001

P5184

8744

01

00

09/10/2019

09/10/2019

SCOUT INFO

REPORT DATE

WELL STATUS

MEASURED DEPTH

TRUE VERT DEPTH

DETAIL

09/10/2019

01

23000

984' FSL & 291' OF SEC 10. PBHL: 1047' FNL & 226' FWL OF SEC 23, ALLEN PARISH.

Views: 3866

Replies to This Discussion

Just a reminder to the laymen that they seldom know who they are interacting with on GHS. 

I like free. Mostly I like this info!

You are not alone, David.  But then again, how many members make a voluntary donation to support the website?  Most likely not nearly as many as receive valuable insight and data.  All members should keep in mind that is cost Keith and Anna to provide this service.

https://gohaynesvilleshale.com/donate

This area also has a high pore pressure environment along with the natural gas production which ultimately leads to higher oil recoveries vs the dead oil ConocoPhillips area.

Marathon updated its presentation with the flow rate of the Crowell well page 20.

1,200 bbls of oil per day of oil and ~9 mmcf of gas on a restricted (code for the well could flow much higher) Pressure at the wellhead is a staggering 9,000 psi!

http://filecache.investorroom.com/mr5ir_marathonoil/218/download/4Q...

Great news Jay!   Thanks so much for sharing with us.   We do appreciate your knowledge & expertise.

If I hear anything else, I will post.  The initial flow rate is in line with others nearby, but the more important factor will be what is the well doing in six months.  

Jay

Based on the completion information filed with the D.O.C., I find it hard to believe that they are happy with that well. While it flowed back over 3500 barrels of fluid, it is basically a water well that produces a little gas and condensate, as also indicated by the relationship of FTP and SITP. 

I looked at some of the adjacent wells in that area and virtually all of them were pretty poor producers...lots of fluid but mostly water. Obviously good permeability...just mostly water. I'm sure Marathon has a lot of information that I do not have but this location just doesn't make any sense to me.

This well is different from all of the other historical wells in that this well was hydraulically frac’d. With this completion method millions of barrels are pumped down the well. A significant amount of this water is recovered during the flowback phase. The 3,500 bbls of water was a rate that was reported on 1/21 which was the first day a flowback. This is why the water rate was so high and the oil rate was minimal.

and we are only seeing what they want us to see, when they want & they have to provide to DNR.   Below is the Completion Report dated 2/3/20.

Attachments:

The API gravity concerns me as does the well cost.  It will take a few months before we see the costs to drill and complete the well.  Early exploration wells are always more costly than later development wells.

I guess what is puzzling to me is that there is no information that indicates that this well was actually fracked. They filed a well history on 10/18/19 and the completion report in early February. 

Regardless, it makes no geologic sense to fracture a high water cut reservoir that obviously already has excellent permeability, as indicated by numerous adjacent wells with extremely high fluid flow rates with no stimulation. 

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