We also have a great partner in our well and Oxy who back in the Gulf, very strong and a very successful private equity company who’s on the lease with us since day one. Very excited about the well. It’s not a simple well to drill. It is also a new seismic data set. OBN type data being shot through this region right on top of the well. That tells you that the industry is greatly interest in the area. The lease sale was greatly interested, and we have a key prospect up in the middle of it. And we’re excited to drill the well. It’s a big well. I wouldn’t — it’s not a low risk well, but it’s the new thing to drill, and we’re happy to have a lease in it. We’re happy to pick up some more in it and we’re happy to see everyone come — get around us there, which means we’re on to the right thing.
We have a great partner with Vicki at Oxy, and we like working with them and a great PE partners is very successful. So we’re very excited about the well and getting back to it.
Charles Meade: So kind of a classic three-way up against salt with a chance to stack up a few sands?
Roger Jenkins: That’s correct. We also have a very nearby prospect called Rushmore that would derisk that, offsetting an area where Chevron bounce and pay years ago, reallocated to other parts of the Gulf. So a good follow-on prospect there, and new leasing in the area, and it could be a new hub in the Gulf BP as a big prospect near here. And we’re excited about the necessary.
Charles Meade: Thanks for the detail Roger.
Roger Jenkins: Thank you. Appreciate it.
Operator: And the next question in the queue comes from Josh Silverstein with UBS. Please proceed.
Roger Jenkins: Good morning, Josh. How are you doing? [indiscernible] you there — Josh.
Josh Silverstein: Sorry. Yes. So the non-core exit of the Duvernay, a little bit of the Montney wonder a full exit of the Duvernay, it’s not been an area that’s received a lot of capital, a little bit of infrastructure constraints. Why don’t you just look at look to exit the whole area? Thanks.
Roger Jenkins: I’ll let Eric go through that. Eric, likes Duvernay. I do too.
Eric Hambly: Yes, I do very much like Duvernay. Josh, we did a really nice job with the Duvernay of conducting a program years ago, fully holding and appraising that asset. And the part of the Duvernay that will remain, I have to say we’re really happy with the performance there from the well performance as well as our ability to get our cost structure to be very competitive. So the economics of those locations are quite strong. And the way we think about Duvernay is, we are not in any kind of pressure to head out there and have activity just to have activity. But as we work through our Eagle Ford inventory and we get from the bulk of our Tier 1 locations in Eagle Ford behind us, the Duvernay really competes quite well with the rest of the Tier 2 and 3 type of Eagle Ford opportunities, and we’ll end up shifting our focus or adding focus rather to the Kaybob Duvernay, because the economics of those locations are really strong, and we’ve highlighted previously in our slides in our call that we have a lot of years of 15 years of shale oil locations between the Eagle Ford and Kaybob that breakeven under $40 a barrel.
So this is a part of a long runway for us of maintaining our shale oil volumes and scale and diversity in our business. And we think of it as core, and we’re really excited about the potential it has to contribute to our business for decades.
Josh Silverstein: That’s helpful and a good segue to the next question, which is the Eagle Ford well performance has been really strong this year. You guys highlighted some of the Tilden wells. How are you guys thinking about capital allocation into the basin? Do you want to try to accelerate some of the activity levels next year because the performance has been pretty strong this year? Thanks.
Roger Jenkins: Yes. Josh, that’s a great question. I always like to talk about our great well performance. So thanks for asking that. We’ve highlighted previously that we were pretty excited to try out our new enhanced completion style in Tilden. We have not until the second quarter of 2023, had a Tilden well online since 2019. So as we’ve featured, we’ve done a lot of work on enhancing our completion design in Karnes and Catarina, and we put it to work here this year in Tilden with two four-well pads. That Jambers pad, we have more production performance data from it than Tino, and it’s showing just great performance, so doubling effectively our production rates on an IP30 basis. The other pad, we saw pretty much in line with expectations.