Greetings and welcome to the Antero Midstream Second Quarter 2020 Earnings Conference Call. At this time, all participants are in a listen-only mode. A question and answer session will follow the formal presentation. [Operator Instructions] Please note that this conference is being recorded. I will now turn the conference over to our host, Michael Kennedy, Chief Financial Officer. Thank you, sir. You may begin.

Thank you for joining us for Antero Midstream’s second quarter 2020 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&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. Before we start our comments, I would first like to remind you that during this call Antero management will make forward-looking statements. Such statements are based on our current judgments regarding factors that will impact the future performance of Antero Resources and Antero Midstream and are subject to a number of risks and uncertainties many of which are beyond Antero’s control. Actual outcomes and results could materially differ from what is expressed, implied or forecast in such statements. Today’s call may also contain certain non-GAAP financial measures. Please refer to our earnings press release for important disclosures regarding such measures including reconciliations to the most comparable GAAP financial measures. Joining me on the call today are Paul Rady, Chairman and CEO of Antero Resources and Antero Midstream; Glen Warren, President and CFO of Antero Resources and President of Antero Midstream; and Dave Cannelongo, Vice President of Liquids Marketing and Transportation. With that, I’ll turn the call over to Paul.

Thanks Mike. I’d like to start by discussing AR's asset sale program which continues to improve AR’s liquidity position and will allow it to repurchase debt at attractive discounts to par. Slide three titled, AR Asset Sale Program Update, details the progress that AR has made to-date on its $750 million to $1 billion asset sale program. During the fourth quarter of 2019, AR commenced its asset sale program with the sale of AM shares to AM for a $100 million. Despite the ongoing COVID-19 pandemic, AR was able to execute a $402 million overwriting royalty interest sale in the second quarter of 2020, including $300 million of upfront proceeds and a $102 million of contingent payments. In July, AR monetized excess 2021 natural gas hedges for proceeds of $29 million. This brings AR’s total completed asset sales to $531 million. These asset sales have allowed AR to reduce total debt by approximately $365 million, since commencing the asset sale program in the fourth quarter of 2019. In addition, AR is in active discussions for further asset sales and we remain confident that we can achieve the $750 million to $1 billion asset sale target in 2020. We believe this positions AR to repay its 2021 and 2022 maturities and significantly de-risks the Antero complex. Before moving on to AR’s liquidity position, I want to briefly touch on AR’s hedge position pro forma for the recent monetization on slide number four titled, Enhanced Natural Gas Hedge Position. In the second half of 2020, AR is 94% hedged on natural gas production at a price of $2.87 per MMBtu. Due to the overwriting royalty interest sale, AR was previously over-hedged of its 2021 natural gas production. As a result, AR monetized a 100 BBtus per day of excess quote-unquote hedges above…

Thanks, Paul. Let's turn to Slide number six, and begin by discussing the NGL macro environment. The effects of COVID-19 on oil and transportation fuel demand, and the resulting decline in rigging completion crew activity in oil focus shale basins, has set up expectations of a prolonged period of depressed us oil production. More notably, this backdrop results in depressed associated NGL production relative to the volumes that were being produced and fractionated just prior to the onset of COVID-19 around the world. The chart on the left-hand side of the slide illustrates that NGL supply forecasts have declined by over 1 million barrels a day since the beginning of this year. Further, it highlights that, it may take several years for U.S. NGL production to return to pre COVID-19 levels, as the momentum of production declines from the dramatic slowdown in U.S. shale activity over the last four months plays out. The chart on the right-hand side of the slide highlights that sufficient export capacity along the Gulf Coast has helped clear the domestic market and tighten fuel pricing to international pricing. Turning to Slide number seven titled, NGL Price Recovery Expected, we can see that the strength of NGL markets relative to WTI and Brent has continued to stay elevated as a result of more resilient petrochemical and residential commercial markets during this pandemic. Here we illustrate the outperformance of Mont Belvieu propane relative to WTI in 2020. On the right, we see a similar outperformance in propane relative to Brent at the Far East Index or FEI, which is the benchmark in Asia. This is important as Antero has exposure to not only domestic NGL markets, but also international destination pricing through our export access on the Mariner East system. While the fundamental backdrop for NGL prices…

Thank you, Dave. I'll begin my comments with second quarter operational results, beginning on Slide number 10 titled, Year-over-year Midstream Throughput. Starting in the top left portion of the page, low pressure gathering volumes were 2.9 Bcf per day in the second quarter, which represents an 8% increase from the prior year quarter. Compression volumes during the quarter averaged 2.7 Bcf per day, a 13% increase compared to the prior year. During the second quarter, AM placed online a new Marcellus compressor station, adding 240 million per day of capacity and supporting the compression volume growth in the quarter. AR's compression capacity was 91% utilized during the second quarter of 2020. Our 50-50 joint venture gross processing volumes averaged 1.4 Bcf per day, a 42% increase compared to the prior year quarter. Processing capacity was 100% utilized during the quarter. JV gross fractionation volumes averaged 33,000 barrels per day, a 22% increase from the prior year. Freshwater delivery volumes averaged a 102,000 barrels per day, a 16% decrease from the prior year quarter. The reduction in freshwater delivery volumes is driven by AR moving to one to two completion crews during the quarter as we discussed in our first quarter conference call. AR is currently operating two completion crews on Antero Midstream dedicated acreage. Moving on to financial results, adjusted EBITDA for the second quarter was $201 million, a 2% decrease compared to the prior year quarter. During the quarter, Antero Midstream only received two monthly joint venture distributions compared to three monthly distributions received in prior quarters, resulting in a $7 million reduction in adjusted EBITDA. Distributable cash flow for the second quarter was a $152 million, resulting in a DCF coverage ratio of one time. Capital expenditures during the quarter were $59 million, a 63% decrease compared to…

Thank you. Ladies and gentlemen, at this time we will conduct our question and answer session. [Operator instructions] Our first question comes from Jeremy Tonet, with JP Morgan. Please state your question.

Hi, good morning.

Hi, Jeremy.

Just want to start off with capital allocation philosophy, if we could. It seems like even if the third JV payment for the quarter came through, the coverage on the distribution would have been pretty tight this quarter. And so just wondering, when it comes to capital -- return of capital philosophy, paying a 22% yield versus increasing share repurchases or paying down debt, just want to see what goes into this distribution level as opposed to reducing it to pursue one of those other avenues, it seems like could be more accretive to buyback units at this point.

Jeremy, we’ve stated our coverage ratio kind of range from the start of 2014, and it's around 1.1 times, so if you did do that $7 million, you would have been at that 1.1 times. So, the quarter was well within our expectations and our philosophy on that paying the dividend. The other thing that influences that is when you look at our free cash flow plus that tax payment, there was no leverage added during the quarter. So the return of capital and the dividend was within our free cash flow. And so, we look at that as well. We look at our capital budget through a shift in time. There's no long lead time and it's decreasing so that free cash flow increases over the next couple of quarters. So that will support the dividend payments. And then you look at our leverage, of course, we're in the mid-three times. So, a very strong balance sheet compared to our peers. So, all of those factors go into when we determine the dividend and we're comfortable with the level that it was at.

Got it. Just in terms of the absolute level of yield, the 22% seems a bit high there. So I just didn't know, like there was a certain level of, I guess, accretion that could be achieved on repurchases where it might make sense to pivot in that direction or if that goes into kind of your thought process in any way?

No, we just expect -- we expect the equity to perform better over time and that yield to come down to match the dividend. It's a volatile quarter. And obviously, there was some weakness in the whole industry. And so, I don't think that yield is reflective of the true underlying fundamentals of the business.

Got it. Thanks for taking my question.

Thanks, Jeremy.

Thank you. [Operator Instructions] Our next question comes from Holly Stewart with Scotia Howard Weil. Please state your question.

Thank you. Good morning, gentlemen. Maybe just one from me, Mike it looks like the processing capacity was a 100% utilized during the quarter. Could you just remind us of the schedule there?

Yeah, so, [indiscernible] is the next plan and Sherwoods at that capacity with 13 plants and that was at a 100% capacity. C3+ is almost entirely complete. And that should come on either later this year or in the 2021. But with that said, AR’s kind of out of maintenance capital. They produce around 3.5 Bcfe a day in the second quarter. So there's not much growth going forward. So Sherwood right now has the ability to handle. It's flowing at above nameplate, but still has the ability to handle the volumes.

Okay, great. And then maybe for, one for Paul or Glenn, just on we saw the take in transaction earlier in the week with CNX and CNX midstream. Just kind of curious your thoughts there?

Yes, I think same here. We share the curiosity. It'll be interesting to watch that transaction. We certainly looked at a combination of AR and AM when we went through the simplification in 2018. As you recall, that was a lengthy process with lots of different outcomes analyzed. And the decision was made for Antero really to separate the governance and convert AM from MLP into a C Corp. So our situation is not really an analogy so just that we'll watch the CNX situation like we said with curiosity. Further, AM is just a much bigger midstream business relative to AR upstream compared to CNX and CNX Midstream. But curious situation, be interesting to watch.

Yeah. Maybe the vice versa AM taking AR.

Thanks for the idea.

That's all I had. Thanks guys.

Thanks Holly.

Our next question comes from Ned Baramov with Wells Fargo. Please state your question.

Hi, thanks for taking the question. Two part, one on the JV distributions. So first, could you maybe talk about the reason for only two monthly distributions being received by AM? And second, it seems the distributions for the two months were $19 million, which would imply 9.5 per month, while you quantify the impact to EBITDA for the third month to be about $7 million, so if we could just talk about the step down in monthly distributions from the JV?

Yeah, the first, it's just simply a timing issue. We only book on when we actually get paid, receive and so we only received to one of these quarters down the road. Obviously, there'll be a catch-up payment or received for now, it's just hard to predict. On the $19 million versus the $7 million, it's generally around that $21 million a quarter for the three months. When we looked at the -- when we budgeted, we budgeted that $7 million a month, so that $7 million probably where the volumes are at right now in excess of where we had forecast. Probably would have been more around that 9 and 10. But when we just highlight the 7 that was actually what was in the forecast.

Got it. That's helpful. And then maybe just switching gears on your supply demand analysis of the North American gas market. Maybe could you just talk about your view on the development of the Haynesville as opposed to the Northeast to fill in the supply reduction from declining production in most other basins?

Well, I think, we've seen a decline in Haynesville. I think the latest numbers I saw was 13 Bcf a day, went under 11 Bcf a day out of the Haynesville in just the last few months. And what is the reason for that, don't know. We would -- we look at the Haynesville as not quite as economic as really the very premium gas basins like Appalachia. And so is it just a capital allocation issue? But we're following it as well. And we do see, it's been a puzzle, I think too many in the industry as to how the Haynesville has stayed so high. And so I don't know the exact answer, but I think, it probably doesn't surprise industry that much that it's declining relative to some of the other gas basin.

Got you. And then last one for me if I may. Are there any updates on the litigation with Veolia that you could share?

There are no updates.

Thanks. That's all I had. Thank you.

Thank you.

Thanks Ned.

Our next question comes from Sunil Sibal with Seaport Global Securities. Please state your question.

Yes. Hi, good morning, guys. And thanks for all the clarity. I just wanted to go back to the Slide 9 in your deck where you talk about the infrastructure build out and the differentials between, say, Northeast and Mont Belvieu. So seems like, second quarter there was probably one-time items and then the regional demand is probably also be the corridor. In addition to the new infrastructure which you talked about the pipeline capacity being expanded, are there other factors that you think would lead to tightening of the Belvieu to the Northeast spread?

Sunil, that's really the primary driver. I mean, the Northeast, its infancy was always at a premium to Belvieu and the market was short NGLs for refinery, gasoline blending for the butanes and pentanes and then propane for the rest comp market. The Appalachia has grown so much now that we've really needed the export outlet to drain the bathtub, as you've heard us say numerous times, that's what has been the key driver. And the arms that will be received out of Mariner East will play a role on what the floor is back in the basin. And we've seen -- we kind of predicted the slide has been shown for some time before Mariner East came online. And now we've witnessed the results over the last year and a half. And it's very much met our expectations of what it was going to do to the floor price in the basin once that was debottleneck.

Got it. And could you remind us on the transport side, you obviously have capacity on Mariner East, than in terms of locking in the far east or the European prices? Do you have contracts on the shipping side also?

We have indexed sales to the Far East Index and the Northwest Europe, but we have not ourselves actually charted the vessels, so we are predominantly selling FOB the markets hooked up dock, but at either a Mont Belvieu ARA or FEI linked price. And so when you sell versus international index, you can somewhat imply what your shipping cost was in the price that you sold the dock at.

Okay, got it. And then one kind of broader question on the leverage and the dividend coverage philosophy. So it seems like, I think in the past you've articulated 1.1X to 1.2X kind of dividend coverage where you're comfortable with and leverage also 3.5X to 4X. So obviously you're staying within those kind of broader parameters at the same time de-risking the overall AR complex of Antero complex. Should we think about you kind of revisiting those parameters at some point of time, obviously if you execute on AR kind of debt reduction strategy, considering that the midstream industry overall has kind of moved beyond those kind of numbers and kind of pointing to more conservative parameters on those two criteria?

Nothing at this time, I think the mainstream industry is trying to get down to our balance sheet or in fact, in the mid-three. I do see some of those coverage ratios going higher for other midstream providers, but that's generally because they may have long term capital projects or other kind of calls on their cash, that Antero Midstream doesn't have. So right now we're comfortable in those ranges that you mentioned.

Okay, got it. Thanks.

Thanks, Sunil.

There are no further questions at this time. I'll turn it back to management for closing remarks. Thank you.

I'd like to thank everyone for participating in today's conference call, if you have any further questions, please feel free to reach out to us. Thanks again.

Thank you. This concludes today's call. All parties may disconnect. Have a good day.