Wells in T11N, R15 & R14W seem to have pretty tepid IP's

I haven't seen any discussion about this but the reported IP's by Chesapeake in T11N, R15 & 14W don't seem to me to be any better than those wells reported in T18, north of I 20. This confuses me because Chesapeake is drilling like crazy in 11/15. So far CHK has drilled 16 wells in 11/15 and reported IP's on three (3) of them: Section 14...4,251MCFD; Section 15...3,003MCFD and Section 25...6,097MCFD. On the west side of 11/14 CHK has drilled four wells and reported IP's on two (2) of them: Section 19...8,670MCFD and Section 30...5,733MCFD. The reported pressures seem to be much lower than other parts of the play as well. There has to be a good reason for Chesapeak to continue drilling the Lower Haynesville and building infrastructure in this area, I just can't figure out what the reason is. Other than Bethany-Longstreet, this is probably CHK's most heavily drilled area but the IP's are 1/2 of that in Bethany-Longstreet. I don't think CHK is stupid so I repeat....there has to be a reason for their continuing to drill the area. Middle-Bossier prospectivity perhaps? Somebody help me figure this thing out! Comstock has some pretty modest wells in the area also.

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Permalink Reply by Parkdota on August 16, 2009 at 7:36
It could have to do with the particular leases they have. Many companies are executing extensions if they're in their contracts due to the poor economy and pricing. So, if they can do that they'll drill where they don't have extension clauses in order to keep leases. I don't have an extension clause nor does my family and Encana is drilling on our properties before others for this very reason. There could be many, many other reasons as well. Maybe one of the pros on this site knows why.
Permalink Reply by Lee on August 16, 2009 at 11:47
I have been watching those numbers also and CHK's IP's are consistently in the single figures in T11, but EOG and Comstock are reporting good wells in T11 and T10 (ranges are a little further east). Per the companys' information, the EOG and Comstock wells have, with one exception, been double digit IP's ranging from 10.0 to 17.0. One possible explanation for CHK's continued drilling in that area is that CHK's flow tests are confirming higher IP's than the state test used for SONRIS -- see the current exchange on the Hall of Fame for the discussion of SONRIS IP's v. Company Release IP's. Just a thought.
Permalink Reply by Spring Branch,mineral owner on August 17, 2009 at 11:47
I still say the reason Chesapeake continues to drill the Lower Haynesville wells in 11/15 has to be the Middle Bossier prospectivity. Otherwise I think they would move their $$$$$ elsewhere in the play.
Permalink Reply by Greedy Landowner on August 17, 2009 at 15:22
They are drilling to HBP. There was a big push about 3 years ago to lease property down there, and those leases are/were expiring.
Permalink Reply by Henry on August 17, 2009 at 22:57
Spring Branch,
I thought the speculation about the Middle Bossier had it more to the east, e.g., in southeast DeSoto Parish?? Can you guess for me as to what parts of DeSoto Parish it might be under?
Permalink Reply by shelby on August 18, 2009 at 1:57
Spring Branch,
Is the infrastructure such in the area to bring the gas to the market advantageously? I would think that if they are drilling to HBP, that there would also be a benefit to accelerate drilling in areas where they can get the gas to the market more cheaply; two birds, one stone.
Shelby
Permalink Reply by Spring Branch,mineral owner on August 18, 2009 at 7:45
Keep in mind that Middle Bossier is very prevalent in Texas and that's not east!
Permalink Reply by Spring Branch,mineral owner on August 18, 2009 at 8:17
Also keep in mind that Comstock reported the BSMC 7 #2H well as their 1st Middle Bossier horizontal well. The well was in the Toledo Bend North Field in 10/14 Section 7 and had an initial production rate of 11.6 MMcfe/day. That is very much in S/W DeSoto Parish. It is producing from the Middle Bossier, NOT the Lower Haynesville.
Permalink Reply by The_Baron on August 18, 2009 at 3:11
When a well is tested, it is not unusual to rune a multi day test at muitiple chokes. The resevoir engineer will study the data and make recomandations about how best to produce. It may be deceided that a high IP could damage the resevoir, or there could be problems with pipeline capacity etc. Also, what you do not see on SONRIS is how the wells pressure changes over the course of the test. You may be able to open the well up aand produce 15 mmcf/d, only to see the pressure drop off too fast. A prudent operator will make dississions based on the long term, not what will work best for the next few months.

Also, I can not speak for HA wells, but other wells I have been involved with can start producing sand if flowed to fast. Sand is injected in during the fracking process to hold open the fractures, the gas can flow through the sand. Having sand come back is bad. Ever seen a sandblaster at work?

It is no secret that public companies will release whatever data looks the best to there investors. The information submitted to the state is for the purpose of receiving an allowable.
Permalink Reply by Spring Branch,mineral owner on August 18, 2009 at 8:32
Not in any way wanting to be critical, but it seems that folks are trying to answer without doing any homewwork on 11/15. Section 14.....4.251 million/day on a 22/64 choke with 4,650 CP.
Section 15.....3.003 Million/day on a 16/64 choke with 4,012 CP and finally:
Section 25..... 6.097 million/day on a 18/64 choke with 5,324 CP. Now 11/15 is pretty far south in the play. As you go south, temps, and pressures are supposed to go up. Does not appear to be happening in 11/15 for some reason. I understand the interaction between choke size, pressure and production, but these are not tiny chokes which are resulting in the tepid IP's and if they were tiny chokes, the pressures should certainly be greater that 4000 to 5000 lb. casing pressures. I still say there is some reason Chesapeake is drilling these $7-8 million wells in 11/15 and it doesn't appear to me to be because of the Lower Haynesville unless CHK just likes to lose money.
Permalink Reply by Les Bamburg on August 18, 2009 at 18:31
SB, one bit of information that may be relevant is the timing of the state potential test. The following well was tested five days after the initial completion and may have still been in the "cleaning up" stage. For example the well was still producing over 400 Bbls per day of water which could impact both pressure and rate performance.

Chesapeake, AT&N Martinez 14 #H1 Well, Serial #239259, S14-T11N-R15W, DeSoto Parish, 4251 Mcfd, 22/64" Choke, 4650 psi Flowing Pressure
Permalink Reply by Spring Branch,mineral owner on August 19, 2009 at 4:47
I'm not discounting your hypothesis Les, but I'm looking at a production report of CHK's from a new well in Bethany Longstreet. Well has been flowing about 6 days and to pick an arbitrary time from the report........ 6:00 PM 22/64 choke; 7,532 psi, 16,824 mcf/day, 18 bbls water/hr., 432 bbls water/day. The proof will be when CHK starts reporting monthly production numbers on Sonris, but I predict the monthly production will be in line with the initial IP's. in 11/15. I hope I'm wrong, but I don't think so. There is a big difference between 4 million/day and 400 bbls frac water amd 17 million/day and 400 bbls frac water. Also a big difference between 4650 psi and 7532 psi. These wells look an awfully lot like the Sharp wells in the northern part of T 18 to me, but CHK is still drilling in 11/15.....Why in 11/15 but not 18/15? Has to be the Middle Bossier looks good on the logs. I just haven't heard another explanation that fits, in my opinion.

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