Replies to This Discussion

Permalink Reply by obed w odom on June 10, 2013 at 9:25

Yes, in the completion report they called it condensate. The gravity was reported as 50, as compared with the 59 gravity reported for the BML well. I'm not sure where the gravity demarcation between oil and condensate is.

Permalink Reply by ddozier on June 10, 2013 at 11:25

It's more dependant on the well classification. Gas wells produce condensate because the liquids fall out of the gas stream as the pressure and temperature changes as the steam flows uphole from the reservoir. Crude is liquid in the reservoir and remains liquid with gas coming out of solution with changes in pressure and temperature. Generally a gas oil ratio of 10000 or greater defines a the well as a gas well. Tha t is a very basic definition without getting into the calculus of enthapy curves, bugbubble points and the like..

Permalink Reply by pip318 on July 15, 2013 at 13:15

month      barrels

05/2013    8939
04/2013    9361
03/2013    9922
02/2013    9078
01/2013    8369

Permalink Reply by North LA on July 15, 2013 at 14:42

That well is sucking all the oil out of the brown dense :)

Permalink Reply by obed w odom on June 22, 2013 at 5:25

I just noticed at SONRIS Lite that a DT-1 test of the WB Exxon Mobil well on 3/30/2013 (reported 5/1/2013) shows that the WB produced 324 BCPD and 449 MCFD on what appears to be an open choke (64/64). Could this be correct? If so, this would represent a large opening up of the choke from the SDM2G test of 1/2/2013 when the well produced 504 BCPD and 1019 MCFD on 10/64 choke, and would imply that the decline rate is greater than it appears.

http://sonlite.dnr.state.la.us/sundown/cart_prod/cart_con_wellinfo2...

Permalink Reply by shale player on June 22, 2013 at 6:38

What we really need to see is the flowing tubing pressure.  As mentioned above, the choke can be opened to maintain the rate until the choke is all the way open, then the true decline rate can be determined. 

Permalink Reply by obed w odom on June 22, 2013 at 7:07

Interestingly, SONRIS Lite reports a flowing pressure of 3500 for both the 3/30/2013 and 1/2/2013 tests, so something doesn't add up. Also, the reported production for the full month of April averaged 312 BCPD, down only slightly from the test of 3/30/2013. If this April production was at 64/64 choke setting, it seems the decline during the month would have been greater.

Permalink Reply by shale player on June 22, 2013 at 7:21

I, along with others, have speculated that WB ran into a fracture system that is feeding their well.  Just like in the Austin Chalk, if natural fractures do exist, you can get some monster wells if you hit the fractures just right.  If this is true, the trick is going to be determining the fracture prone areas and drilling there.

With the possible exception of the Dean vertical test, it does not look like SWN has had the luck(?) that WB had in terms of hitting fractures.  They just seem to be drilling in areas where their casing is falling apart. 

Permalink Reply by Big Little Oil on July 18, 2013 at 7:24

This well has grossed ~$5mm in six months so far...as a vertical. It is likely a 400k+ bbl EUR?

If they drill an horizontal well on this unit, it'll be huge.

Permalink Reply by Skip Peel - Mineral Consultant on July 18, 2013 at 7:41

If SWN or any other operator considered a horizontal here a slam dunk, I think W-B would have found them by now.  Of course W-B could be asking more than a larger operator is willing to pay at this point in time.  Regardless, why would any operator want to drill horizontal wells at $10-$12M per each if they thought they could get similar long term production from vertical wells at $1 - $1.5M? 

Permalink Reply by Big Little Oil on July 18, 2013 at 8:19

Something else is at play with this W-B well proximity. If there were no barriers, the pipepline would have been in place in 2010 and there'd be dozens of verticals(despite horizontals bringing higher recoveries) all around this well.

This well is outperforming Eagleford verticals by 4X. Even the Dean 31 horizontal is performing in line with Eagleford verticals. A horizontal here by the W-B well could turn some heads, it appears, as this well had no fracks. What would a 5400' wellbore with 20 stages do in this well's rock?

Permalink Reply by North LA on July 18, 2013 at 8:35

Isn't this well on Exxon fee? If so then I would think Exxon wouldn't be in a hurry to do much with but would rather just see it as a shelf project.

• ‹ Previous
• 1
• 2
• 3
• 4
• 5
• 6
• Next ›
• Page