Unidentified Analyst: To start off kind of a 2-parter on the volume outlook. I was wondering if you could provide a breakdown of that 10% G&P inlet growth assumption in ’23 between the Mid-Con and Bakken. And the second part of that question was kind of what’s the right way to think about volumes and EBITDA growth in ’24 if you guys have 20-plus rigs on your acreage for 2 to 3 years.
Kevin Burdick: I think we did provide the breakdown by Mid-Continent versus Rockies and the materials for the guidance range for ’23. So that’s in the materials. As we think about the growth, we’ve mentioned that it takes roughly 15 rigs on our acreage to hold volumes flat. So clearly, if we’re sitting north of 20 rigs on our acreage and those rigs stay there, we’re going to experience growth. And that would include growing ’24 over ’23 if the activity levels remain kind of where they’re at today in the Bakken. And that would also hold true for the Mid-Continent as well You’ve also got the rising gas to oil ratios. So as we move through time, the gas-to-oil ratios have continued to trend up, which is also going to be a tailwind for volume growth as we — especially if we’re keeping these activity levels.
Unidentified Analyst: Got it. Appreciate that. And then I appreciate that you guys spoke on frac fees a bit earlier, but just wondering if maybe you guys could provide a rough sense of what third-party frac fees look like per quarter in ’23 and then maybe for 2024 as well given like the incremental volume growth maybe could we think about third-party frac fees in the $100 million range for ’24?
Sheridan Swords: Yes. I don’t — we’re not going to break down our factories just for competitive reasons on how we go through ’23. But it’s very to say that what we’ve got from the insurance company is going to cover what we’re going to pay to third-party fracs in ’23 and ’24.
Operator: Today’s last question comes from Sunil Sibal with Seaport Global Securities.
Sunil Sibal: I just wanted to confirm one thing with regard to your comments on the Medford fractionator. I think you mentioned that you considered that to be fully contracted — so is it fair to assume that all your third-party frac leads for 2023 and 2024 are kind of contracted at this point of time?
Walter Hulse: Yes. Yes, that’s a good assumption.
Sunil Sibal: Okay. And then on the Saguado gas pipeline, in addition to the FERC approval, I was curious what are other kind of getting items for that project? And could you look at a kind of a JV or a partnership for that pipeline? And then lastly, would you look to finance all of that, if that were to move ahead on your balance sheet or you could look at some other ways to finance.
Kevin Burdick: Sunil, this is Kevin. I mean we’re still, again, early in the process from the pipeline perspective. It would be an intrastate pipeline. So — we wouldn’t need other FERC approvals as it relates to actually building the pipeline if it did reach FID. As far as partnerships go, we are looking at it as we would own the pipeline at this point, but as with anything, if there’s a strategic and economic reason for us to have a partner, we would consider that. But again, at this point, we’re approaching it like we’re going to our pipeline would just be part of that entire pipeline service that would get gas to the Gulf Coast — or excuse me, get gas to the West Coast of Mexico.
Sunil Sibal: Got it. And then on the financing side, all on the balance sheet or…
