S20-T15N-R14W Chesapeake Haynesville Unit, Well Permit and Drilling Rig

Chesapeake Operating: (1) submitted a 640 acre Haynesville unit application for Section 20 dated 3/24/10, (2) a Baton Rouge hearing on the application was held 5/4/10, and (3) the field order No. 191-H-104 dated 6/7/10 designated S20-T15N-R14W as Haynesville Zone, Reservoir A, Unit HA RA SU156.

Chesapeake obtained a horizontal well permit (242547) dated 12/21/10 that expires 6/18/11, and according to Keith Mauck's “Drilling Rig Locations” discussion on January 14 the Chesapeake #58 drilling rig has been assigned.  The Sonris website for this well is:


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


I have been considering a proposed Chesapeake lease for several months for depths below 6500 feet. If or when a HA well is drilled will that resolve the question about this section being HBP by the shallow Pettit well No. 220475 in the southwest corner of Section 20 just South of the Texaco station? 
There 2 dwellings in the Southwest corner of Section 20 so that may explain why the proposed drill site is 908 ft from the South section line but why is the bottom hole location 990 feet from the West section line?

Tags: Chesapeake, Haynesville, Unit, permit, well

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Permalink Reply by Robert Griffin R on January 17, 2011 at 4:59
More files for S20-T15N-R14W:
Attachments:
Permalink Reply by Skip Peel - Mineral Consultant on January 17, 2011 at 5:10
The question of HBP would be answered by the language in the applicable leases.  Lacking any depth clause, all depths would be HBP by the Pettit well.  All leases which do include a standard depth clause would be free to lease the depths below the existing production.  The surface location is likely required to meet the state set back regs.  The vertical well bore will angle back toward the south section line before building its curve for the lateral.  The penetration and perforation points are 990 feet from the west line to allow for another lateral between this well and the western unit boundary line.  The drainage area for this well will be approximately 660' with 330' of that to the west leaving a remaining 660' to accommodate a later well.
Permalink Reply by Ezra on July 28, 2011 at 11:00
Skip- do you know of any situations with Haynesville wells where a landowner has successfully challenged an old lease (1980's; 1990's; with an active shallow well) that did not contain a depth clause. I sure hate to miss out on bonus money.
Permalink Reply by Skip Peel - Mineral Consultant on July 28, 2011 at 11:06
Yes, but the specifics are important and you do not cite any.  If the "active shallow well" has been continuously produced and the volume of production meets the legal test for minimum production to maintain the lease, then that old lease is still binding.  It's actually a good bit more complicated than that but here again we are back to specifics.  Depending on the size of your mineral interest it may be worth your time and money to have an experienced O&G attorney review the historical production under the old lease.
Permalink Reply by Robert Griffin R on January 19, 2011 at 9:58

Well 242547 in S20-T15N-R14W was spud on 1-7-11.  Drilling at 9168 ft on 1-17-11.

 

WELL HISTORY

SERIAL WELL NAME WELL NUM ORG ID FIELD ST CD PT WELL CLASS EFF DATE END DATE STAT DATE
242547 HA RA SU156;JONES 20-15-14 H 001 C084 2360 01 00 12/21/2010 12/21/2010

SCOUT INFO

REPORT DATE WELL STATUS MEASURED DEPTH TRUE VERT DEPTH DETAIL
01/17/2011 05 9168 DRILLING
01/10/2011 05 2685 SPUD 1-7-11; SET 10 3/4 TO 1868' W/ 843 SX; DRILLING
12/21/2010 01 17500 908' FSL & 513' FWL OF SEC 20. PBHL: 250' FNL & 990' FWL OF SEC 20.
Permalink Reply by Robert Griffin R on March 11, 2011 at 4:14

Update 3-11-11:

SPUD 1-7-11; Reached Total Depth of 16,423 feet on 2-6-11 (30 days)

Preparing to run production casing.

 

REPORT DATE WELL STATUS MEASURED DEPTH TRUE VERT DEPTH DETAIL
02/07/2011 09 16423 TD 2-6-11; PREP TO RUN PROD CSG
01/31/2011 05 11655 SET 7 5/8 TO 11,159' W/ 1306 SX; BUILDING CURVE; BOP TEST 1-27-11
01/24/2011 05 10720 PREP TO RUN INT CSG
01/17/2011 05 9168 DRILLING
01/10/2011 05 2685 SPUD 1-7-11; SET 10 3/4 TO 1868' W/ 743 SX; DRILLING
12/21/2010 01 17500 908' FSL & 513' FWL OF SEC 20. PBHL: 250' FNL & 990' FWL OF SEC 20.
Permalink Reply by kittycatmama on March 11, 2011 at 13:32
look at Sec. 21 of 15/14. Supposedly there is a fault in that section (does it go into sec. 20?)  Could that be why the lateral is so far from the west line
Permalink Reply by Robert Griffin R on March 12, 2011 at 4:32

KCM,

On page 10 of the attached file "Bossier Faults" Petrohawk's shale map shows a narrow gray fault line running southwestly from Wallace Lake down across the NW corner of Section 21 and ending in the far SE corner of Section 20.  Go to the 400% scale in the PDF file to see it better.  I can only guess that this is a possible reason why the well was placed on the west side rather than the east side of the section.  See Skip Peel's comment on January 17 above regarding the fact that there is still space for another well between the south-to-north lateral for 242547 and the west section line.  Looking at the image file for Section 20 you can see that some of the properties including homes on the east side of the north end of Burford road extend eastward into the NW corner of the section.  This may have had something to do with the decision to not drill the first well closer to the section line.  Good luck to you.

Robert

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Permalink Reply by kittycatmama on March 12, 2011 at 5:51
for the first time i can see the fault. Thanks for the info. Okay, I have reserved minerals in sec. 21. Viewing the fault, will the operator be able to drill 8 wells into this section with the fault crossing the northwest corner
Permalink Reply by Robert Griffin R on March 12, 2011 at 9:45
Please keep in mind that the information shown on operator shale maps may only be approximate sketches.  I assume that data from seismic testing may show the depth and vertical offset of fault lines at specific locations, however, I have no knowledge of how seismic data is used or how accurate it is.  Only your operator can answer your question about 8 wells.
Permalink Reply by Robert Griffin R on July 26, 2011 at 13:15

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

 

Sonris Scout Report as of 7/26/11:  12-stage frac completed 5/16/11, turned to sales 5/23/11, waiting on pipeline 5/30/11, which was nearly 2 months ago.  Anyone know status or progress on pipeline?   Nelson and Kelly CHK wells in adjacent sections 18 and 19 had only 9 and 10 frac stages, respectively, in 2009.  Has 12-stage frac become more common over the last 2 years?

 

SCOUT INFO

REPORT DATE WELL STATUS MEASURED DEPTH TRUE VERT DEPTH DETAIL
05/30/2011 36 16423 WAITING ON PIPELINE
05/23/2011 09 16423 TURN TO SALES
05/16/2011 09 16423 FRAC STG 12; WAITING ON PKR
05/10/2011 09 16423 FRAC STG 1-11
02/07/2011 09 16423 TD 2-6-11; PREP TO RUN PROD CSG
01/31/2011 05 11655 SET 7 5/8 TO 11,159' W/ 1306 SX; BUILDING CURVE; BOP TEST 1-27-11
01/24/2011 05 10720 PREP TO RUN INT CSG
01/17/2011 05 9168 DRILLING
01/10/2011 05 2685 SPUD 1-7-11; SET 10 3/4 TO 1868' W/ 743 SX; DRILLING
12/21/2010 01 17500 908' FSL & 513' FWL OF SEC 20. PBHL: 250' FNL & 990' FWL OF SEC 20.
Permalink Reply by Skip Peel - Mineral Consultant on July 26, 2011 at 13:31
Yes, 12 stage fracs are common.  And the number is still increasing along with variations in perforation designs.  It is not unusual to see 14 stage fracs now in HA units.

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