Antero Midstream posts 10% EBITDA increase, $78 million free cash flow, and continues strategic expansion in core Marcellus Shale assets.

OPERATOR - (00:03:36)

Greetings and welcome to the Antero Midstream third quarter 2025 earnings call. At this time, all participants are in a listen only mode. A question and answer session will follow the formal presentation. If anyone should require operator assistance, please press Star 0 on your telephone keypad. And as a reminder, this conference is being recorded. It is now my pleasure to introduce to you Dan Kassenberg, the Director of Finance. Thank you sir. Please go ahead.

Dan Kassenberg - Director of Finance - (00:04:05)

Thank you for joining us for Antero Midstream's third Quarter investor conference call. We'll spend a few minutes going through the financial and operating highlights and then we'll open it up for Q and A. I would also like to direct you to the homepage of our website at www.anteromidstream.com where we have provided a separate earnings call presentation that will be reviewed during today's call. Today's call may also contain certain non GAAP financial measures. Please refer to our earnings press release for important disclosures regarding such measures. Joining me on the call today are Michael Kennedy, CEO and President of Antero Midstream, Justin Agnew, CFO of Antero Midstream, and Brendan Kruger, CFO of Antero Resources. With that, I'll turn the call over to Mike.

Michael Kennedy - CEO and President - (00:04:47)

Thanks Dan. Good morning everyone. In my comments, I will discuss our 2025 capital budget and strategic initiatives. Justin will then walk through our financial results for the quarter. Let's start on slide number three, titled Investing in the Core of the Marcellus Shale. The maps on this page depict the core outline as we knew it upon Antero Resources 2013 IPO compared to where we see it today. As step valve development has proved up acreage over the last decade, the core boundaries continue to expand in the Marcellus along with improving well results. These results have driven an increase in organic leasing program at AR and an expansion of AM's infrastructure. This organic expansion of both AR and AM is a core initiative at both entities and positions us well for the structured change in natural gas demand over the next several years. During the quarter, AR acquired approximately $260 million of assets in this core area. This included transactions acquiring working and royalty interest which were already gathered by am, as well as additional core acreage. The acreage acquisition was not dedicated to a midstream provider and resulted in 10 additional locations dedicated to AM along with the grassroots leasing program. This brings the total locations acquired year to date and dedicated to AM approximately 80 locations, more than offsetting the 2025 development plan. Looking at AM's capital investment during the third quarter we invested $51 million bringing our year to date capital invested $133 million or approximately 75% of our total budget. At the midpoint of guidance, this capital included significant investments in water assets to expand and connect the southern end of the Marcellus Shale. This investment provides development flexibility and unlocks significant low cost inventory across the liquids rich midstream corridor. I also want to touch on some new initiatives on the dry gas portion in West Virginia of our acreage highlighted in blue on slide number four. With only a small investment by am, AR is now planning to drill its first dry gas Marcellus pad in over a decade. This pad is located on existing infrastructure with underutilized midstream capacity that AM acquired in 2022. This pad highlights the speed the market ANTERO can deliver on a coordinated basis with Antero midstream and significant dry gas optionality. Our midstream infrastructure will allow AR to immediately access local markets as proof of concept for future in basin demand growth from data centers and power generation projects or if local basis were to tighten. This dry gas development results in attractive rates of return for AM and more importantly significant upside to our previous acquisition that was valued on a PDP only basis. In summary, we continue to remain active in our expansion efforts, leveraging our existing assets to drive growth and capitalize on the structure change in demand for natural gas. With that, I'll turn the call over to Justin.

Justin Agnew - CFO - (00:07:59)

Thanks Mike. I'll start with our third quarter financial results on slide number five. During the third quarter gathering compression volumes increased by 5% year over year driven by another quarter of uptime availability over 99%. Adjusted EBITDA was $281 million which was a 10% increase year over year. This was driven primarily by an increase in gathering processing and freshwater delivery volumes. Freshwater delivery volumes increased by almost 30% year over year while operating just one completion crew, which is a testament to the significant completion efficiencies achieved over the last year. This EBITDA growth combined with declining capital resulted in free cash flow after dividends of $78 million which was a 94% increase compared to last year. We utilized this free cash flow for share repurchases and debt reduction, which drove our leverage down to 2.7 times as of September 30th. I'll finish my comments on slide number six titled Balance Sheet Strength and Flexibility. Over the last year we've reduced our absolute debt by approximately $175 million and taken our leverage down by almost a half a turn. This credit improvement resulted in credit ratings upgrade from Moody's and ability to refinance our nearest maturity notes that were due in 2027. This transaction, which was upsized due to significant demand, extended the maturity to 2033 at the same 5.75% coupon. Pro forma for this refinancing, we have over $870 million of liquidity and no near term maturities. Our balanced approach to debt reduction and share repurchases has allowed us to reduce our financing costs further compounding the growth and free cash flow after dividends. In summary, AM's balance sheet is in the strongest position since our IPO over a decade ago. Our capital investments continue to deliver consistent free cash flow, which we expect to further expand as we head into 2026. This expanding free cash flow positions us well to return additional capital to shareholders and continue to expand our growth opportunities across both the liquids, rich and dry gas portions of our asset base. With that operator, we are ready to take questions.

OPERATOR - (00:10:16)

Thank you. We will now be conducting a question and answer session. If you would like to ask a question, please press Star one on your telephone keypad. A confirmation tone will indicate that your line is in the queue. You may press Star two to remove yourself from the queue. For participants using speaker equipment, it may be necessary to pick up your handset before pressing the star keys. One moment please while we poll for questions. And the first question comes from the line of Jeremy Tonant with JP Morgan. Please proceed with your question.

Jeremy Tonant - Equity Analyst - (00:10:52)

Hi, good morning.

Michael Kennedy - CEO and President - (00:10:55)

Morning.

Jeremy Tonant - Equity Analyst - (00:10:57)

Just wanted to turn to the topic of in basin demand specifically as it relates to the potential for behind the meter opportunities. And I believe Antero talked about being in discussions there and looking at this and just trying to get a sense for I guess how near or later term this is. You know, just trying to get a a feel for that and whether customers are looking for prices pinned to just in Basin or is Henry Hub part of the conversation wondering how this all mixes together?

Brendan Kruger - CFO - (00:11:27)

Yeah, this is Brendan just to touch on the in basin demand and behind the meter. I think we've talked about it in the past. You know, Antero Resources is one of the largest consumers of power in the state of West Virginia at the Sherwood Complex. So we've talked about it in that light in the past where you could go behind the meter. That would accomplish a couple of things. One would reduce overall operating costs for Antero Resources on the power side of things. And then secondly you'd obviously free up incremental grid power if you were to go behind the meter in that scenario. So obviously it takes a lot of different parties to work through solutions such as that. So no timeframe on our end. Still analyzing, still having discussions around opportunities like that. And then in addition, you know, we've mentioned in the past, but we do feel the Antero family is very well positioned as it relates to data center opportunities to the extent they take hold in the state of West Virginia. I think Antero resources produces about 40% of the natural gas production in the state. Highly integrated with Antero Midstream, Midstream has the water system that it's invested about $600 million in. So significant water system which can be helpful in power infrastructure. So a lot of good attributes between the two parties that we think could play out well. But still ongoing discussions at this point and no set time frame.

Jeremy Tonant - Equity Analyst - (00:13:06)

Got it. Understood. And on this Sherwood behind the meter potential project here, what are the specific, I guess hurdles at this point that you know, would stop, I guess moving forward?

Brendan Kruger - CFO - (00:13:20)

You know, there's a lot of different pieces to it as it relates to, you know, equipment availability and making sure you have the right agreements in place from a power perspective with utilities in that area. So, you know, I think still quite a bit of hurdles just to get something across the finish line. So again, no near term announcements expected on that as we sit here today.

Jeremy Tonant - Equity Analyst - (00:13:45)

Got it, thank you. And then, you know, as regards to, you know, the underutilized assets that fit quite nicely, you know, given the dynamics there, just wondering, are there other, I guess pockets across your footprint where the same potential could unfold going forward where there's underutilized assets that could, you know, step into new production, that provides, you know, the strong accretion?

Brendan Kruger - CFO - (00:14:07)

Yeah, you know, midstream was early and doing all these bolt on acquisitions has really consolidated the play. And so we bought the Crestwood asset, which is the dry gas kind of portion in 2022, bought Summit as well in 2024, which is kind of in that more lean gas area. So those two areas and those comprise a significant amount of acreage, probably about 150,000 acres in total are all underutilized right now from both a high pressure and compression perspective. So a lot of available availability there for Antero Resources to develop into entera midstreams, underutilized capacity.

Jeremy Tonant - Equity Analyst - (00:14:51)

Got it. That's helpful. I'll leave it there. Thanks.

OPERATOR - (00:14:57)

And the next question comes from the line of Yvonne Scotto with ubs. Please proceed with your question.

Yvonne Scotto - Equity Analyst - (00:15:05)

Hey, thanks for taking my question. I wanted to ask about the 10 undeveloped locations that AR acquired. What kind of capital or infrastructure Spend is needed on your end for connectivity to those locations.

Brendan Kruger - CFO - (00:15:19)

Not very material. I mean it's within our core areas. So generally when I think about it. And this is just a good rule of thumb, it's about a million dollars per well when you think about it from a LP and water and then it's already tied into compression and HP. So you know, incrementally maybe $10 million.

Yvonne Scotto - Equity Analyst - (00:15:38)

Okay, got it. Thank you for that. And then just based off of your free cash flow growth and leverage of 2.7 times, how should we think about capital allocation priorities moving forward?

Brendan Kruger - CFO - (00:15:51)

Yeah, good question. I think you know, for now we're still focused on debt reduction and repurchasing shares. We've had a fairly balanced approach year to date. It's obviously ebbed and flowed a little bit on a quarter to quarter basis. But you know where the shares are trading today, we obviously see a lot of value in repurchasing shares and there's obviously some benefit and value of paying down debt. It provides you with a lot of flexibility and you saw the benefit in terms of refinancing the note. So I think looking forward it's still going to be that balanced approach. Roughly 50, 50 of share repurchases and debt reduction.

Yvonne Scotto - Equity Analyst - (00:16:24)

Okay, great. Thank you.

OPERATOR - (00:16:30)

The next question comes from the line of John McKay with Goldman Sachs. Please proceed with your question.

John McKay - Equity Analyst - (00:16:36)

Hey everyone, thank you for the time. I wanted to touch on some of these comments around, you know, drilling into where AM has some open capacity. You called this kind of first drag as well as, as a bit of a proof of concept but you know, I guess is the current AR plan to kind of lean more in this direction. Really what I'm trying to get to is, you know, could we see the effective capital intensity for AM per incremental M of AR production come down if you're moving into those, those windows. Or is this again a kind of, hey, we'll see how we develop the dry side.

Brendan Kruger - CFO - (00:17:14)

I mean I think it's the back. Half, you know, we'll see how it goes. But if that does occur it would be. AM's capital intensity would be much lower obviously because we already have infrastructure in the region.

John McKay - Equity Analyst - (00:17:29)

And maybe just a follow up to that is. Yeah, I mean you are calling it a proof of concepts I guess. Is this, you know, is this a comment on your side on the liquids outlook and you know, more enthusiasm for the dry side or is this a, hey, people that are looking at us for in basin solutions do kind of want to see us be able to execute on, on the dry piece as well.

Brendan Kruger - CFO - (00:17:52)

Yeah, it's the second it's in basin but also, I mean it's not a bad thought on the first. You know we do have the diversity of product here and the ability to toggle between liquids and dry gas from both upstream and midstream. So you look at a $4 gas curve versus backward dated oil curve and so that would suggest that dry gas has become more economic on a relative basis. So that is something that's optionality for us from both midstream and upstream. So the proof of concept is really for the in local demand but at the same time it is. It could be a portfolio approach as well.

John McKay - Equity Analyst - (00:18:29)

Makes sense. Thanks for time.

OPERATOR - (00:18:35)

There are no further questions at this time and I would like to turn the floor back over to Dan for any closing remarks.

Dan Kassenberg - Director of Finance - (00:18:41)

Thank you everyone for dialing in to the call today. Please reach out to us with any questions that you have. Have a good day.

OPERATOR - (00:18:50)

And thank you everyone. That does conclude today's teleconference. We thank you for your participation. You may disconnect your lines at this.