Apache has released information on their new Liard Shale play located in British Columbia, Canada west of the Horn River Basin. The initial horizontal well produced at an average rate of 21.3 MMcfd over 30 days from a 2900 ft lateral and just 6 frac stages. This dry gas play would be a good source of feed gas supply for the Kitimat LNG export project operated by Apache.
A set of slides describing the play are attached.
Any thoughts on if there may be some natural fracturing they may have hit, making this look "better" than it is?
If I review the slides right, they are showing 67 BCF/well with an 18 stage frac (hypothetically). It would only take 720 of those wells to get the 48 TCF....
Dbob, you are close but see Slide 87 - 65.9 Bcf/Well & 731 well locations.
Most shale gas plays have some level of natural fracturing that contributes to the well performance. This play's performance seems to be related to the rock quality, formation depth and pressure gradient. The key will be if the rock quality is consistent across the entire play.
I guess what I'm getting at - in some areas of the Austin Chalk, operators have hit very long, prolific natural fracture systems that make for absolute monsters. Of course, most wells don't hit that, and tend to drag averages down. From a shale standpoint, until more tests are done, is there any way to validate APC's claims?
Dbob, the information from Apache regarding the rock quality and initial well test looks reasonable but it will take a lot more drilling results to validate their development model.
Thanks for the fyi.
Does that rank the Haynesville Shale down to 3rd behind this and Eagleford or are we much lower than that?
Bobi, it depends upon the criteria used for the ranking. For gas productivity the Haynesville Shale would rank above all existing shale gas plays (excluding the new Liard play). Based on economics the Haynesville Shale would fall below several of the existing shale plays for the next few years.
The situation could improve for the Haynesville/Bossier Shale play toward the end of the decade if suppliers need natural gas for the Gulf Coast LNG export projects.