Again, the plus of is you’ve got a state that knows our geology very well, lots of resources. And we’ve seen demonstrated in the 2 states that have it, the speed of that turnaround to really increase. North Dakota has actually a CCS project that just started up this past week. After a permit made it through in less than 6 months. So we’re very encouraged that when the states take over, we can get these on to a more timely time line, but regardless, even if it’s 2 or 3 years to process through EPA, it fits within our overall project time lines.
Unidentified Analyst: Got it. Got it. And then Bayou Bend, you’re planning to spud another — or planning to spud the first well in the fourth quarter. What’s the estimated cost for a well now? And how long do you think that’s going to take?
Robin Fielder: Yes. So we’ll be spudding that first stratigraphic test well. This is a data acquisition well where we’re going to be doing pretty extensive logging and core collection again, to help calibrate our model, but really supplement that first application that will go to EPA and also eventually into the railroad commission as we’ll take a similar approach there keeping both agencies in the loop. As far as the cost there, I mean, it’s going to depend for that one being offshore, obviously, there’s a little bit more costly to get a jackup or drill that. That’s what we’re waiting on right now is the rig is still with another operator. As you do these onshore, they’re fairly straightforward wellbores. We’re talking a vertical wellbore from the range of 6,000 to 8,000 feet.
So nothing very sophisticated, and that’s — the main cost difference will be if we decide for these wells to become keeper wells, where we’re going to reutilize that wellbore for either monitoring an injector. Because if we do that, we’ll run a corrosive resistant pipe or if it’s just a pure data acquisition well, you can just suspend the well and P&A to be much less costly. So it really depends on where we’re at and what that is. But as far as the overall investment in the CCS projects, the drilling of the wells is one of the smallest.
Operator: This concludes our question-and-answer session. I would like now to turn the conference back over to Tim Duncan for any closing remarks.
Timothy Duncan: Thanks for joining the call, everybody. I think one of the themes at this quarter is, obviously, third quarter is always a noisy quarter with respect to potential downtime related to weather. We saw that we’re trying to have a strong exit. We’re pulling as much value forward as we can. We’re trying to get some wells online. We’re trying to pull value forward in our business, we pulled value forward in our Mexican asset. And so I think it’s been a year of really trying to do the blocking and tackling that it’s going to take the long-term value. And so we talked about next year, next year, I think we’re going to focus our attention on materially more free cash flow generation than this year as we’ve had a what I would call a moving year.
So I think we’re happy with where the business is. There’s a lot of work to do. There’s a lot of things to get online, a lot of more value to pull forward. But I think we’re trying to do the right things. And as we think about joint venture structuring, on building long-term — long-term inventory development as we think about the initiatives again to pull value forward on these catalysts. I think the team is doing the things that it needs to do is going to generate value. We’re looking forward to kind of a strong exit and a robust start to 2024 and being in touch with the investor community on how that’s going. So thanks for joining the call.
Operator: The conference has now concluded. Thank you for attending today’s presentation. You may now disconnect.
