EnLink Midstream LLC (ENLC) 2021 Q1 法說會逐字稿

Good day and welcome to the EnLink Midstream First Quarter 2021 Earnings Conference Call. (Operator Instructions) Please note this event is being recorded. I would now like to turn the conference over to Brian Brungardt, Director of Investor Relations. Please go ahead.

Thank you, and good morning, everyone. Welcome to EnLink's first quarter of 2021 Earnings Call. Participating on the call today are Barry Davis, Chairman and Chief Executive Officer; Ben Lamb, Executive Vice President and Chief Operating Officer and Pablo Mercado, Executive Vice President and Chief Financial Officer. We issued our earnings release and presentation after the markets closed yesterday and those materials are on our website.

A replay of today's call will also be made available on our website at www.enlink.com. Today's discussion will include forward-looking statements, including expectations and predictions within the meaning of the federal securities laws. The forward-looking statements speak only as of the date of this call and we undertake no obligation to update or revise. Actual results may differ materially from our projections and a discussion of factors that could cause actual results to differ can be found in our press release, presentation and SEC filings.

This call also includes discussion pertaining to certain non-GAAP financial measures. Definitions of these measures as well as reconciliations of comparable GAAP measures are available in our press release and the appendix of our presentation. We encourage you to review the cautionary statements and other disclosures made in our press release and our SEC filings, including those under the heading Risk Factors. We'll start today's call with a set of brief prepared remarks by Barry, Ben and Pablo and then leave the remainder of the call open for questions and answers.

With that, I would now like to turn the call over to Barry Davis.

Thank you, Brian and good morning everyone. Thank you for joining us today to discuss our first quarter 2021 results. After 2020, that was a challenging year, a one in which our performance exceeded expectations, the first quarter of 2021 was a continuation of that strong performance. I am incredibly proud of the relentless effort our employees made during winter storm Uri, not only to ensure the integrity and performance of our assets, but also to ensure people's homes could be heated and powered and that impact to the communities we serve would be short term in nature. I am particularly thankful that they did that while remaining safe.

For the first quarter, EnLink delivered another strong resilient quarter. We achieved adjusted EBITDA of $249 million and free cash flow after distributions of $94 million, both of which exceeded our expectations. When you drill down into our segment performance, we achieved another quarter with all 4 asset segments generating significant cash flow. This is a tremendous outcome given the unprecedented temporary volatility winter storm Uri presented and speaks to the operational excellence focus we have had over the last few years.

Overall, Uri had a minimal net impact to our first quarter results. Despite the unprecedented, temporary impact, the volumes across all our segments. Importantly, all of our systems are back online and volumes have returned to normal. With the strong first quarter results, we remain positioned to meet our full year 2021 adjusted EBITDA and free cash flow guidance. Our focus for 2021 continues to be one of execution with 4 key areas that our team is working on today.

First is operational excellence and innovation. We have been laser focused on this. We have centralized some compressor station and plant monitoring to enhance the cost and scalability of operations. And we have fully embraced an efficiency mindset, which has led to operating our business better each and every day. Second is financial discipline and flexibility. With our focus on operational excellence, we continue to reduce operating and G&A expenses in the first quarter. And we continue to forecast another year of very strong free cash flow after distributions with the ability to continue to pay down debt.

Our third focus area is strategic growth. We have previously discussed our disciplined approach to opportunistic accretive bolt-on acquisitions. Yesterday, we announced an acquisition consistent with our strategy with the Amarillo Rattler system in the Midland Basin. The Amarillo Rattler acquisition builds on our longstanding relationship with Diamondback Energy and offers another example of using operational synergies to achieve attractive economics. In terms of business development, we continue to see our Louisiana footprint offering growth opportunities. In addition to new projects like the Venture Global project we completed last year, our extensive asset footprint and long-standing customer relationships position us well to collaborate with others in the energy transition over the long term. And our fourth and final focus area is sustainability and safety. Providing safe, reliable operations is the foundation of sustainability at EnLink and the cornerstone of our operational excellence.

You'll see the clear evidence of this through our third Annual Sustainability Report issued last night and available on our website. Yesterday, we advanced our goal of being part of the energy transition and being an active participant in it. As we build our path towards a long-term remission goal, we have established emission reduction milestones, which include striving for a 30% reduction in methane emissions intensity by 2024 and pursuing a path to reach a 30% reduction in our total carbon dioxide equivalent emissions intensity in our operations by 2030.

These milestones will build a path to our long-term goal to reach a net zero emissions by 2050. Lastly, to remain united with our industry in addressing the environmental impact, we also joined the environmental partnership.

With that, I'll turn it over to Ben to talk about operations.

Thanks, Barry and good morning everyone. Before we get into the segments, I want to thank our team for their efforts to manage the business during winter storm Uri. The storm was an unprecedented event that temporarily disrupted volumes across all of our asset segments and created a number of operational challenges. Negatively impacting the quarter, we purchased gas at extremely high market prices to cover firm sales as volumes received from producers on our systems fell.

We experienced other marketing-related losses including losses on derivatives that in normal times are used to ensure price stability and predictability. In spite of the challenges presented from the severe decline in customer volumes, EnLink's resilient assets helped to create offsetting operational savings. We were able to make limited incremental commodity sales to support local markets in less operationally affected regions.

Additionally, as a result of forced outages on our systems due to the unavailability of volumes from producers and from power outages, we received approximately $40 million in credits for unused electricity, that had been purchased on a firm basis. Our focus on operating efficiently and safely helped set the foundation for us to respond swiftly to the challenges the extreme temperatures presented. Our team is prepared for the storm by pre-positioning heavy equipment to ensure that we could accessed our assets, reducing the levels in our storage tank, so that we could operate without truck access for a period of time and having detailed plans for how to keep our employees safe as they responded to this unprecedented event. These actions and others helped to contain the operational impact to a window of about 10 days. We are incredibly proud of the work our employees did during this unprecedented event. Our team worked tirelessly to ensure that all of our assets operated to the greatest extent possible, because we know that our products are essential to the lives of those in our communities. Additionally, I want to add on to Barry's earlier comments on the Amarillo Rattler acquisition. We are extremely excited to deepen our long-standing relationship with Diamondback Energy, one of the most successful Permian focus producers. At a cost of $60 million, the acquisition represents attractive economics of about 6 times on 2022 expected EBITDA. Thanks in part to significant operational savings and it requires minimal CapEx for system integration.

Now, moving to the segment results. The Permian continues to see robust activity and generated $42.8 million in segment profit. Additionally, the first quarter of 2021 marked the third consecutive quarter of positive segment cash flow with $29.5 million being generated. Average natural gas gathering volumes were 1% lower compared to the fourth quarter of 2020, but increased by approximately 11% over the first quarter of 2020. Average natural gas processing volumes for the first quarter were 3% lower compared to the fourth quarter of 2020, that increased by approximately 2% over the first quarter of 2020.

The sequential decline in gas volumes on our system was due to the temporary, severe volume disruptions we saw from Uri. For example, we saw volume reduced as much as approximately 90% on our Midland gas system before returning to normal operations. When we look at March 2021 volumes, gathering and processing volumes increased over 12% and about 7% respectively over December 2020. Project War Horse our Midland Basin plant relocation continues to make good progress and it remains on schedule to be in service in the second half of 2021.

Given the current commodity environment and level of producer activity, we anticipate that War Horse will be highly utilized shortly after start-up. Turning now to Louisiana. Segment profit for the quarter was very strong coming in at $82.2 million. This represents an increase of almost 2% when compared to the seasonally strong fourth quarter of 2020 and a 9% increase from the first quarter of 2020. Louisiana saw very strong cash flow generation of $79.4 million during the quarter and we continue to forecast strong cash flow for the remainder of 2021. The segment benefited from strong NGL prices, the recent inception of the Venture Global Transportation agreement and the acquisition of Jefferson Island storage and hub. The recent acquisition of the Jefferson Island assets also helped to balance our system and ensure that our firm Louisiana customers including utility, power and industrial users continue to receive service during winter storm Uri. And despite the addition of the acquired assets, our focus on operational excellence benefitted the segment as operating expenses declined over 8% year-over-year.

Moving up to Oklahoma. We delivered $55.5 million of segment profit for the first quarter of 2021, which was approximately $43 million lower than the fourth quarter of 2020. The first quarter of 2021 marks the first quarter following the expiration of a minimum volume commitment. This MVC accounts for approximately 40% of the decline relative to the fourth quarter of 2020. Despite the MVC rolling off, Oklahoma continues to be a very strong source of cash flow, which was approximately $54 million in the first quarter of 2021. Natural gas gathering and processing volumes decreased by about 10% sequentially. Similar to what we saw in the Permian, average volumes for the first quarter of 2021 were significantly impacted by the volume disruptions associated with Uri, which saw temporary reductions of over 90% in Oklahoma.

The JV project between Devon and Dow began development under its 2-rig program. We continue to expect to begin receiving volumes in the second half of 2021. Additionally, we expect to see slightly higher levels of activity from private operators given the current commodity price deck. We think both of these factors may help provide momentum into 2022. Wrapping up in North Texas, segment profit for the quarter was $76.9 million, which increased by approximately 25% compared to the fourth quarter of 2020. Additionally, we saw very strong segment cash flow generation with approximately $75 million in the first quarter of 2021.

Our team in North Texas is doing an incredible job managing the asset base and was able to reduce operating expenses by 6% compared to the first quarter of 2020. Gathering volumes for the first quarter of 2021 declined 3% when compared to the fourth quarter of 2020, due in part to the impact from Uri. While volumes were negatively impacted by the storm, we were able to support the local market during the storm with some limited incremental gas sales at higher than normal prices. North Texas is a mature basin that we have been encouraged by some recent activity. A private operator drilled 4 very successful new wells on our system in the first quarter and BKV has been reactivating old wells and re-stimulating active wells. This kind of activity can help to reduce the overall decline rate of the basin.

With that, I'll pass it over to Pablo to discuss our financial updates.

Thank you, Ben and good morning everyone. I'll start with the first quarter highlights. As Barry mentioned, EnLink delivered a strong first quarter, achieving $249 million of adjusted EBITDA. The team overcame significant volume disruptions and operational challenges created by the winter storm in addition to the Oklahoma MVC roll-off.

EnLink also achieved $94 million of free cash flow after distributions for the first quarter of 2021 with all 4 of our asset segments delivering strong contributions. As Ben highlighted, winter storm Uri temporarily impacted all 4 of our segments. However, in aggregate the storm did not have a material impact on our first quarter results. On a segment level basis, Oklahoma was the hardest hit since it did not have significant offsets to counter the volume impact to our systems. We estimate that Oklahoma was adversely impacted by approximately $15 million.

North Texas on the other hand saw a net positive impact of a similar magnitude. The effects of winter storm Uri on our industry are far ranging and resulting industry wide litigation and billing disputes will take time to resolve. In addition to our team's performance through the February storm, we're incredibly proud of the work they have done to focus on operational execution and gained efficiencies since 2019.

Operating and G&A expenses in the first quarter of 2021 were down 13% year-over-year, excluding the $40 million electricity credits resulting from Uri and Project War Horse OpEx of $7.6 million. We continue to see the significant cost reductions that we achieved in 2020 as a 100% sustainable in 2021 and a large portion of them about 85% to 90% sustainable even in a modest growth environment. On the capital expenditures front, the team continues to keep a sharp eye on capital-light high return projects as exemplified by Project War Horse. For the quarter, capital expenditures net to EnLink were only $28 million, which is down from $91 million in the first quarter of 2020. We do however anticipate CapEx to take up starting in the second quarter as we proceed with project War Horse and other well connect activity. In total, we continue to expect capital expenditures to be between 140 and $180 million in 2021.

On the balance sheet side, one of our top priorities is to maintain our strong liquidity and financial position and we continue to make progress on debt reduction. During the quarter, we reduced our bank debt balance by $100 million and increased our cash position.

We continue to be well positioned to repay our remaining $350 million term loan balance this year, given our strong free cash flow generation and our $1.75 billion undrawn revolver. Also in the first quarter, we expanded our AR securitization facility by $50 million to $300 million, while simultaneously lowering the cost by almost 40 basis points to LIBOR plus 125 basis points.

At the end of the quarter, we had only $150 million drawn on that facility giving us additional liquidity. Our debt to adjusted EBITDA ratio under our credit agreement was 4.2 times at quarter end. Reducing leverage below 4 times continues to be our objective and we will likely set a lower objective over time. Now as we look ahead with the strong first quarter under our belt, we feel very good about our guidance range of $940 million to $1 billion of adjusted EBITDA and $275 million to $325 million of free cash flow after distributions.

We continue to see solid operator activity, which should drive higher volumes in the second half of the year and what we have seen some volatility in commodity prices, current forward curves for NGLs and WTI remain above the assumptions used in our guidance. For reference, as discussed last quarter, our guidance was based on average prices of $0.55 a gallon for NGLs $3 per MMBtu for natural gas and $50 a barrel for WTI.

That said, there's still a lot of year yet to play out. So we will look forward to providing a further update with respect to our guidance on our second quarter call.

Turning to capital allocation. We remain committed to a disciplined and balanced allocation of our free cash flow, while deleveraging the balance sheet remains our top objective, we have the financial flexibility to peruse other high return opportunities and return of capital to unitholders. We continue to evaluate small tuck-in acquisition opportunities around our existing footprints. But like the Amarillo Rattler acquisition, those investments will have to clear high bar with respect to returns and not impede our deleveraging objective.

We did not repurchase any of our equity or debt securities in the first quarter, but continue to have that flexibility as we generate cash and balance our capital allocation objectives.

With that, I'll turn it back to Barry.

Thank you, Pablo. To sum it up, I am very proud of all the hard work and dedication the team has shown to put us in this position and showcase the resiliency of our asset footprint during this past quarter. We're well on our way to meet our 2021 guidance and continue to lay the foundation for this to be our class in terms of EBITDA.

Additionally, we are laying the path to be active participants in the energy transition. With that, you may now open the call for questions.

(Operator Instructions) The first question will be from Shneur Gershuni of UBS.

Maybe to start off, I was just wondering if we can talk about the Oklahoma segment for a bit here. When I sort of think about the segment several years ago, you were coming off a very active period and when the rig count decline you're finding high decline rates just because of the newer wells, you had the NBC roll-off at the end of last year. And so I guess kind of my question is, are we at the point where the decline rates are more manageable? Can you talk about where it goes from here, have rigs returned to the footprint? If so how many? Can we assume with the flattening of decline rates that not as many rigs are needed to keep Oklahoma flat especially when I sort of take into account the 14% reduction in OpEx year-on-year. Any color would be super helpful in helping us think about the Oklahoma Segment on a go-forward basis?

Shneur, good morning, it's Ben. Yes. A lot of little sub-questions there, but let's just kind of lay the foundation. Obviously the storm makes it difficult to see in our reported first quarter results sort of the underlying volume trend that -- I'll share with you that if you were to look at March versus December, which is about the fair comparison you have in a pretty noisy quarter. The gathered volumes were down about 2% and I think the process volumes were down about 5%. And so that gives you some sense of what's going on the footprint with relatively little activity today.

In terms of rig activity, right at the moment, we have 3 running. 2 of those are the Devon Dow JV rigs that we expect to be on the footprint all year long. And we expect to see first volumes from that activity in the second half late summer, early fall. And the third rig is the private operator and that's been pretty consistent. We've seen one or 2 rigs for our private operators alongside the 2 from the Devon Dow JV. What I would tell you is the private guys in the current price deck, especially with some more robust NGL pricing that really comes into play in the combo play that Oklahoma is, I expect we'll see a moderately higher level of activity from the private guys in the second half. And I think that combined with the Devon Dow JV sets up to carry us with pretty good momentum into 2022.

And maybe as a follow-up question. I know I asked this on almost every call. But I was wondering if we can talk about the operational excellence program. I think on the last call, if I remember correctly, you talked about how much you achieved last year and when you first embarked on it and that you were working on 20 potential different concepts now. Trying to understand kind of what your expectations are around it? Is it something where we see another round of big improvements in '21 or is it something that we have to wait for till '22 and they're more a little bit longer-term in nature? Just any color around your expectations around that in terms of those from an OpEx reduction perspective, but also from a revenue optimization perspective.

Yes, Shneur. Well, you're right. We did a tremendous amount of good work in 2020 and that really showed up in -- not just in OpEx, but also in G&A. We call it operational excellence. But there's certainly a strong G&A component to it as well. And Pablo in his prepared remarks talked about some of the OpEx comparisons and we talked about some of those 2 in the earnings release. But when we look forward, we do have a very robust pipeline of operational excellence opportunities. I would say, that in 2020 we got a lot of the low hanging fruit. 2021 we're doing some of the harder work, some work around technology implementation that we think will pay dividends in future period. So are we going to see another 20% year-over-year reduction? No, I don't expect to see that. But I think what you will see is we will continue to grind cost out quarter-after-quarter on a volume adjusted basis.

So as the business grows, the cost base and actually wants to grow and our operational excellence effort will help to keep that cost base inject or even push it downward.

And the next question will be from Michael Cusimano of Heikkinen Energy.

So correct me if I'm wrong. But I believe the Amarillo Rattler JV had a processing plant planned that they had tabled through 2020, is that right?

Yes, that's correct Michael. Well, let's now go ahead ask question.

So I guess my question was, were they starting to run into capacity restraints to where that plant was going to be revisited from a CapEx standpoint?

Yes. Here's what I would say. They had planned to build a small processing plant on that footprint. And I think that as all of us in the energy sector, thinks through the right way to do our business. Investing in a small processing facility on a relatively small gathering system that maybe doesn't have a ton of visibility to long-term becoming a big system is probably not the right thing to do. And I think the Diamondback team recognized that in the hands of EnLink. We could operate that system at much lower cost and integrate those volumes into our broader system.

And today includes 5 processing plants and would one under construction. And so there is both an efficiency benefit and also a reliability benefit from not had it all of your eggs in one basket so to speak.

So there is enough capacity in your system to where no new greenfield plants needed right now volumes could be better?

Yes, that's right. I mean we have the War Horse plant under construction. That's our plant relocation project from Oklahoma to the Midland Basin. So our near-term expectation is that we'll operate the Amarillo assets until the time that War Horse becomes available. I'd also say though that one of the best things about our team is when we give them some assets to work with, they find new and creative ways to use them and that may end up being the case here closely.

Well, good job your team. I think most will agree that capital efficient agreements like this or a big positive for our industry. So kudos to you all.

I appreciate that and the secret as you can appreciate is having some operational synergy and also having some downstream integration and that's what made it possible for Diamondback and Amarillo to exit at a price that they feel good about and for us to enter in price that we feel good about.

The next question comes from TJ Schultz of RBC Capital Markets.

Let me just start on North Texas, some new join was successful. So outside of the strong impact on first quarter, just what are your expectations for that drilling activity and some of the re-stimulations you talked about the impact kind of the volume declines that we've been saying?

Yes, Thank you, TJ. Great quarter in North Texas fighting through the storm, operations team all the across EnLink did a great job certainly they did in North Texas. When you think about the volume, we did have 4 new wells drilled in the first quarter, they were great wells. Some of the best wells we've seen in the Barnett probably ever they were lean gas wells and have been great, great performers. I don't necessarily expect that, that translates into consistent rig activity at this point. I do think they probably gets the attention of some private operators and I think that combined with some price decks that is sustained over time, would bring some activity back to the -- back of the footprint. In the meantime though, BKV has been a wonderful customer for us to have as Devon successor on the biggest acreage footprint in North Texas. They've been extremely active reactivating a number of the wells that had not been active, that added maybe 3 or 4 billion cubic feet a day. Also experimenting with some re-frac and re-stimulation techniques that has been successful. And so those 2 things together over time ought to help stem the decline on North Texas. I think it's probably a little bit too soon to start quoting specific numbers. But that essence that activity, we expect to see a -- sort of a high single-digit number. And so to the extent that we see some activity like this will help to stem that.

Just my follow-up would be, around the storm impacts a lot of moving parts in the quarter. My question is just really around the comment and some of the billing disputes coming out of the storm. What is the potential impact to you all from any potential or outstanding litigation around that?

Yes. TJ, it's Pablo. So as you know from others, the storm created quite a mess in our industry. Everyone force measured everyone else and so it's going to take some time for those things to get resolve. I think from our perspective, we feel good about our position on all that and what we reflected in the first quarter, are those things that we were able to bring to resolution pretty efficiently.

The next question will be from James Kirby of JPMorgan.

Maybe just want to start here with the newly announced emission reduction goals. You guys mentioned the opportunities on Slide. And it seems, I guess the most immediate would be the -- or I guess the most capital-intensive that is near term would be the compressor engines and drain them to further procedure. I was wondering if you could allocate or talk through kind of what the capital burden would be for that or any kind of early budgeting stages that you've gone through and so how much capital that would take?

Yes. James, this is Barry. Thank you for the question. Let me again say that the work that the team has done on this has been terrific work. We've had a large group across the company from all different departments who have just really done extensive work to get a handle on our emissions and how we can continue to get better there. And so we're proud of the targets that we've set. We feel confident that we'll be able to hit those intermediate targets that we've established and we have a pathway, a specific pathways to each one of those. That being said, we're not ready at this point to put a number on the capital. I will tell you that it is going to be a relatively modest amount of capital because we're doing the things that are closest and the things that can be done very efficiently. I think you hit on the point that is correct, which is when we start getting into switching out any of the compressor engines to move from gas-fired to electric fired, we are certainly going to see that. But I'm going to ask you for some patience for us to establish better capital numbers and communicate that to you in the future.

And then, maybe just a follow-up actually stick to the guidance. You mentioned more color coming into 2Q earnings. But maybe just, where we stand now looking at the commodity price curve oil-sands above where you guys are budgeting for? And maybe just with current activity levels has messaging changed in terms of what is needed to kind of get into the high end of guidance versus low-end or is that really just activity driven? And I guess as we start through April and first few days of May, how are we seeing activity relative to kind of the budgeting acquisitions here?

Yes James, it's Pablo. Great question and happy to provide color. Activity has been good and we're optimistic about that continuing, particularly with the price backdrop, very similar to what we said in the call last quarter, the current price environment, if it hangs in there is sufficient to put us towards the high end of the range. And so we're optimistic. We're off to a good start with a very strong quarter and we continue to gain momentum, both on the volume side and the Permian that we expect to ramp in the second half as well as on the cost control side that Ben touched on.

The next question comes from Gabriel Moreen of Mizuho.

This is Chris Jeffrey on for Gabe. We just had one left. About the Permian crude volumes, we noticed that they were down due to timing of producer completion activity. I was just hoping some more color on that and whether the volumes are now kind of running at former level?

Yes. Chris, it's Ben. If you just kind of look at the evolution of volumes, so if you go back 2 quarters to the third quarter of '20, it was 99,000 a day. Then, in the fourth quarter, it popped up 20% to 120,000 a day. And then, in the first quarter of '21, we were at 108,000 a day. So a couple of things going on there.

In the fourth quarter, we had some pretty robust completion activity and we saw some flush production. So you've got the benefit of that and that's what drove a 20% increase quarter-over-quarter. Now going from 120,000 to 108,000, you didn't have as much flush production in 1Q, but you did have 10 days of storm impact that held us back a bit. Andso maybe that kind of helps you with the trend. The crude volumes from my perspective were in line with our expectations by its nature, just because it's a smaller business for us.

It can be a little bit lumpier than our gas volumes are just depending on when wells get completed returned to sales.

The next question will be from Chris Tillett of Barclays.

I just wanted to circle back on the JV here for a second. I guess first you mentioned in that 6x multiple, there were some operational savings built into that. So I was just wondering if you might be able to quantify how much of those savings are built in?

Yes, I don't want to get into the nuts and bolts too deep there Chris. But let me give you a little bit of a sense. I think from Diamondback and Amarillo's perspective, the business today was not generating much cash flow. From our perspective, we have not only the operational synergies, we also have some downstream integration with our NGL business that provides some value to us that others might not be in a position to capture. And so between those 2 things, from our perspective, it looks like about a 6 times on next year's EBITDA. I'll add, we're not banking on an enormous amount of volume growth to achieve that. The volume flowing today is on the order of 13 million cubic feet a day. Our number for next year is something like 17 million cubic feet a day. It's not heroic assumption. And Diamondback actually has 2 rigs working on acreage dedicated to Amarillo as of today. So we feel good about it. And like I said earlier, M&A works well when -- from our perspective, we feel good about the price, 6x to us, from Diamondback's perspective, it looks like selling cash flow and selling not very much cash flow at all for $60 million to $75 million.

I mean I guess is there much capital required to integrate your existing assets with the system?

There is not. If you look at the map, you'll see that the gathering system lies right on top of us. And so it's a pretty efficient integration plan. We're talking $1 million to $2 million when everything is set and done.

And then, I guess, last on that. You guys have mentioned that the gathering agreement was amended. Are you able to provide any color on what in the agreement was amended?

Yes. So the bigger picture here is we have a dedication -- a significant dedication from Diamondback in this university lands area. I think it's actually 4 different contracts that we've done with Diamondback over the years. And that lies right alongside the Amarillo dedicated acreage. And so what we did was we put in place an agreement for the Amarillo acreage that is similar to our other agreements. And we also extended the terms of our existing agreements. So that now that most of that area is dedicated to us and we'll be able to serve it more efficiently under one consolidated acreage position.

(Operator Instructions) Seeing no further questions, I will turn it back to Barry Davis for any closing remarks.

Thank you Carrie for facilitating our call this morning and thank you everyone for being on the call today for your support. As always, we appreciate your continued interest and investment in EnLink. We look forward to updating you with our second quarter results in August. In the meantime, we wish you all well and stay healthy. Have a great day. Thank you for joining.

Thank you, sir. The conference has now concluded. Thank you all for attending today's presentation. You may now disconnect your lines. Have a great day.