Welcome to the MPLX First Quarter 2020 Earnings Call. My name is Sheila and I will be your operator for today’s call. At this time, all participants are in a listen-only mode. Later, we will conduct a question-and-answer session. [Operator Instructions]. Please note that this conference is being recorded. I will now turn the call over to Kristina Kazarian. Kristina, you may begin.

Good morning and welcome to the MPLX first quarter 2020 earnings webcast and conference call. The synchronized slides that accompany this call can be found on mplx.com under the Investors tab. On the call today are Mike Hennigan, President and CEO; Pam Beall, Chief Financial Officer; and other members of the management team. We invite you to read the Safe Harbor statements and non-GAAP disclaimer on Slide 2. It’s a reminder that we will be making forward-looking statements during the call and during the question-and-answer session that follows. Actual results may differ materially from what we expect today. Factors that could cause actual results to differ are included there as well as our filings with the SEC. Now, I’ll turn over this call over to Mike Hennigan for opening remarks.

Thanks, Kristina. Good morning and thank you for joining our call. Let me start by sharing with you some of the steps that we've taken in response to the current COVID-19 crisis, which has affected all of us and has impacted the demand for hydrocarbons for which we provide services. To better protect the health and safety of everyone, in mid-March, we asked many employees to start working from home, so that those employees who must be onsite to run our operations could have a space they need to properly social distance and implement other protective measures. I appreciate the professionalism and flexibility with which all our employees have approached this change to how we work and I especially want to thank those employees who continue to run our business every day. Thank you for the commitment you've shown to our company and those who rely on essential products and services we provide by continuing to ensure this important work is done safely and with excellence. Second, we are grateful for everyone working on the frontlines of this pandemic. This is quarter to support the efforts of our healthcare workers across the country, our sponsor MPC donated 575,000 N95 masks to 46 different hospitals across the country. We will share some of MPLX's global support efforts later in the call. As we progressed through the quarter, we worked to adapt to this very dynamic situation created by COVID-19 pandemic and oil price tensions. MPLX had a relatively strong quarter as the impact of demand destruction began to impact the business in late March. Earlier today, we reported adjusted EBITDA for the first quarter of 2020 of $1.3 billion, which is consistent with the prior year first quarter. In this environment, we are taking proactive steps to reduce our 2020 capital…

Thanks, Mike. I'm pleased to report that MPLX delivered strong results for the first quarter with adjusted EBITDA of $1.3 billion and distributable cash flow of $1 billion, which provided continued strong distribution coverage of 1.44 times and leverage of 4.1 times. As Mike mentioned previously, we announced proactive steps to reduce our capital spend and forecasted operating expenses to offset the expected impact of lower volumes through our assets caused by the COVID-19 business environment. Slide 9 provides first quarter Logistics and Storage business segment highlights. Total pipeline throughputs averaged 5.1 million barrels per day, an increase of approximately 2% versus the first quarter of 2019. Terminal throughput averaged 3 million barrels per day for the quarter, a decrease of 8% versus the first quarter of 2019. This decrease was primarily attributable to planned and unplanned downtime at some of MPC's refineries. During the first quarter, the Wink-to-Webster Permian crude oil pipeline project, in which we have a 15% equity ownership interest of the joint venture continues to progress. We continue to expect that the pipeline system, of which 100% of the contractable capacity is committed with MVCs, will be placed in service in the first half of 2021. The Whistler natural gas pipeline project also continued to progress. The 2 Bcf per day capacity project, which is more than 90% committed with MVCs, is expected to start up in the second half of 2021. Slide 10 provides first quarter Gathering and Processing business segment highlights. Gathered volumes averaged 5.8 billion cubic feet per day, representing a 3% decrease versus the first quarter of 2019. This decrease was primarily driven by unplanned downtime related to a producer customer in our Utica dry gas region. Marcellus and Utica gathered volumes averaged 3.2 billion cubic feet per day, a 5% increase…

Thanks, Pam. As we open the call for questions, we ask that you limit yourself to one question plus a follow-up. We may re-prompt for additional questions as time permits. With that, we will now open the call to questions. Operator?

[Operator Instructions]. Our first question will come from Shneur Gershuni with UBS. Your may go ahead.

Mike, first off, congratulations on your new role. I'm not sure you may want it in this environment. But nonetheless, congratulations. Maybe to start off, I was wondering if we can talk about the L&S segment kind of on a broad basis. And I do appreciate the color around the MVCs that were put in the presentation today on Slide 5. But when I sort of think about -- maybe it’s hard to look at 1Q performance as we kind of think ahead given the environment. It’s widely reported that refined product demand has fallen significant during the last two months. And we have seen some green shoots, week-over-week improvements, UBS Evidence Lab study kind of confirms that. But I was wondering if you can talk about how much of the Q1 EBITDA in that segment is repeatable in Q2 or said differently is protected by MVCs with both MPC and some of the third-party capacity owners?

Hey, Shneur, good question. So, one of the things that we tried to do was give a little bit more color on the MVCs in general, since everybody has been asking around that question. Let me give you the high-level macro view on the L&S and then Pam can give even a little bit more color on the numbers. So first off, at a high level, I mean everybody is aware that demand for gasoline and diesel and jet fuels had a dramatic change as a result of the pandemic. We nominally said gasoline kind of hit a floor of around 50% reduction overall, that kind of puts it in a general average position, a little bit more on the West Coast, a little bit less in the Gulf but call it overall about 50%. We're cautiously optimistic that we're seeing a little bit of recovery, maybe 5% to 15% depending on the area, but we still have a long way to go. So, we have cautious optimism that recovery is starting to occur. At the same time, we still have 30 million barrels of light product inventory over the 5 year average and 50 million barrels of crude over the 5 year average. So, there's still a long ways to go. MPC is guiding at minimum rates continuing in the second quarter. So, the MPC system has basically cut back to about two-thirds of its capacity. So that has an impact on the L&S business, which is -- which you are asking. So, let me let Pam give you a couple more numbers that'll add to our prepared remarks, that'll give you a little bit more insight into that -- what that cost would look like in the quarter.

Yes. Hi, Shneur. As Mike said, we've tried to take a stab at looking at what would be the EBITDA impact if we were at minimum volume commitments for the full quarter to give you a sense for what that might be. Now, we also tried to highlight in the slides that not all the services that are provided to MPC are subject to volume risk and MVCs. A lot of them do have fee-for-capacity and are not subject to that volume swing. But we took a stab at that and we think it'd be about $150 million hit to EBITDA for the quarter if we were at minimum volume commitments for the entire quarter. The other thing I just want to highlight, we have other sensitivities. One sensitivity that we've provided in the past consistently is the NGL price sensitivity. And that remains at about for every $0.05 change in the NGL price basket, it's about 23 million a year. And so, if you think about our first quarter, the average that we experienced was about $0.40 a gallon, and right now we're about $0.30 a gallon. So, if we held flat here in the second quarter for the full second quarter, that $0.10 change for the quarter would probably be somewhere around $11 million to $12 million for the quarter. One other thing I just wanted to highlight while we're talking about sensitivity Shneur is that curtailments. We've had questions about that from a number of investors. So, just based on the curtailments that we see at the moment, we think that could be as much as $40 million to $50 million in the quarter. So just trying to put -- we're not giving guidance for the year, we're not giving official guidance for the second quarter, but those are some sensitivities that you could use if you want to make assumptions about, if these conditions remain for the full quarter or for only part of the quarter, we thought it might be helpful to give you that data.

That was super helpful and really do appreciate the transparency there. Maybe as a follow-up question. You announced pretty steep CapEx reductions for 2020, far steeper than we were thinking. And you also had some comments about how you expect to be free cash flow positive after distribution in 2021, but you didn't say that about 2020. Should we just assume that you're probably cash flow neutral or close to that this year? Is there any color around how we should be thinking about that for 2020?

Yes, Shneur, it's Mike. So, yes, it'll be obviously pretty close to your point is, on paper it could be a little bit one way or the other. We had originally said that we thought we would get there by 2021 and that was predicated on the higher capital number. So, your point is well taken. With the lower capital number, we're just going to have to see how the rest of the year plays out. Obviously as we mentioned in the prepared remarks, the situation on natural gas has improved considerably as a result of the shut-in of associated gas in the Permian, et cetera. So, one of the major changes in the capital program -- and I want to be really clear about this is the original BANGL project we are no longer pursuing. Just reminding everybody that we had FIDed Whistler and we had FIDed Wink-to-Webster, but we had not FIDed the BANGL project. But I don't want people to take away from that, that we're not committed to still servicing our producers with flow assurance. We've just changed the view of that to use some existing pipe that we're working with some other parties. So, the original scope is now what we are not pursuing, which changes the capital quite considerably. I know the market has been wondering about that for a couple quarters in a row. And we said many times that we want to make sure we have a solution for producers, at the same time, there's still a lot of interest in going to an area that's outside of Bellevue. So that's still all holds. The situation is such that the volume expectation is such that the capital requirement for the project needed to change, and that's where we're headed right at this point. So overall, we're still committed to NGL solution. However, the original scope is what we're deferring or putting to the side at this point, and we have a new scope that's included in our guidance here on the capital reduction. So, you can see a pretty significant reduction as a result of that. Hopefully that all makes sense to you.

Thank you. Next we'll hear from Jeremy Tonet with JP Morgan. You may go ahead.

This is Charlie on for Jeremy. Just following up on some of the last comments there. I understand that you're still targeting free cash flow generation in '21. Just curious if the recent down cycle, how that’s kind of impacted your view on what the right level of leverage is as it relates to the 4 times that you've talked about in the past? And then kind of following on that, as you look at capital allocation next year, how that might influence how you view leverage versus buybacks?

Yes, so let me just highlight one additional thought that I should have shared when Shneur asked the question about the potential impact to EBITDA. So obviously, the ability to get to free cash flow positive starts with EBITDA, and the strength of that. And so as we mentioned today, as Mike mentioned, we also have a sound $200 million of operating expense reduction, so that's going to help offset a significant portion of what we think is going to be the impact to EBITDA here in the second quarter of lower volumes across the system. So, I just wanted to get that out there too as we talk about some free cash flow. That's going to be an important element of our strategy to offset that volume impact. But then when we think about free cash flow, there are just a few levers that we have, and certainly managing capital is one of them. And maintaining an investment grade credit profile and maintaining our distribution to our sponsor are important. So when we think about leverage, we're very comfortable where we are at 4.1 times, we would feel comfortable seeing leverage go up to a higher level, recognizing that it would not be there, permanently, we'd be bringing it back down. Over the longer term, we feel comfortable with leverage. And I think everyone in the space has been moving their leverage down, not up. And so 3.5 times to 4 times is an area that we will feel comfortable operating-in in the future. And then when we get to that place where we have excess cash flow, which will be a nice luxury to have, we'll determine if we'll use that for additional debt reduction or if we'll return it to shareholders in the form of unit buyback. So getting a little less leverage in the whole financial system will give us that flexibility to determine how to best create value for the unitholders.

Just a second question on your CapEx program. You kind of talked through 2020. Just curious on any thoughts, high level, on 2021. I think that number was $1 billion that you put in last quarter's slide deck. Just curious if there's any thoughts there on potential deferrals?

Yes. We haven't given a lot of color yet on where 2021 will play out as we have -- see how this pandemic continues to play itself out. Like I said, earlier, I think we have cautious optimism that we're starting to recover. But as I mentioned, there's still a long way to go here. So, right now, we're just concentrating on the 2020 plan. And then as the year progresses and we get to see how this plays out and we’re -- we'll give a little bit more disclosure on where 2021 will be.

Our next question will come from Spiro Dounis with Credit Suisse. Your line is open.

Just want to go to the Northeast, if we could. Look like you’ve tabled some Northeast processing expansions. At the same time it seemed like Northeast actually has a tangible growth potential again. So I guess how are you thinking about Northeast capital allocation going forward? Have you made a decision to diversify within the basin? Or could we actually see you pivot back at some point?

Spiro, I think the situation on gas is obviously changing quite a bit with the current reduction in associated gas. I mean we stated on many calls previously that our view was that the Northeast was still a stable amount of cash flow for us and we expect that the producer community to be stable even in the previous environment. So, obviously that hasn't changed. And if anything, it looks like it’s stronger opportunity for the Northeast to maintain or slightly grow. And that's kind of been our position all along. There has been some concern about the absolute level of natural gas price and what that does to the producing community. But as everybody can see, the 2021 strip is now north of $2.75 or so. And even in the current situation, we're above $2 in the near-term. So -- but I think the situation has changed quite a bit as far as the dynamic on absolute gas price, hasn't changed our view as to what we think is occurring there. And you've heard a lot of disclosure from the producer community up there. But -- so, I think we stated all along we thought the Northeast would be a good source of cash flow for us. We thought it was going to be maintained. We have never been a believer there was going to be a large reduction in the volumes up there even prior to this situation. But obviously now that this situation has played itself out a little bit more, there is more security in gas prices and gas volumes for the Northeast.

Switching to Permian now just a little bit. I guess can you just update us on the broader strategy there. I know at one point the goal was to build out that super system and look everything has sort of changed now. Just curious maybe where that stands and you’ve augmented that strategy? And then in that context and just thinking around the BANGL and the related fracs, it sounds like you’re still moving forward with the frac side of that equation. Just curious, can you walk us through the commercial interest that was really driving those two projects to stay to some degree on the board. And can you just clarify on BANGL on the new plan there to provide a flow assurance. Are you planning to offload onto someone else's NGL pipe, are you actually talking about partnering on an existing NGL pipeline?

Yes. So on the first part of the question, we're still committed to the Permian growth that's going to occur, albeit now slower. So one of the things that we've been trying to do in that business as you’ve heard is, have discipline around the investment and where we're putting our capital and the Permian still in our view is still a good long-term area. Obviously in the short-term with crude price in the low 20s, the expectation for producers to adapt to that is not unexpected. We hesitated as you know, for several quarters we’ve talked about because the capital commitment for the original scope was a much larger commitment and we wanted to have a surety of the volumes. Well, the current situation obviously has changed that. So, we're still committed to the area. But we are working with existing assets that are out there and we are still committed to an NGL solution. It just won't be the original scope that we had envisioned early on. So, I can't give you a whole lot more color there as Tim and his team is working on the commercial situation as far as putting our NGL solution together. But I do believe, like I said, all along the industrial logic for the project still holds. Now the pace of volume is such that it'll be a little slower as producers adapt to the current environment, which we certainly understand. And I would tell you that I think this is part of what we've had in our mind all along as we wanted to not commit to that full scope until we were really sure that the volume commitments would be there. What's happening in the market, obviously, and we understand it, is the volume commitments are slower and therefore the capital requirement needed to adjust. And that's kind of what we've done with the project. So still believe in the industrial logic, still believe in the projects. Overall goal, still believe in producer outlets for NGLs that also holds just the scope of how we attack it, is what's changing.

Our next question will come from Michael Blum with Wells Fargo. Your line is open.

I was wondering if you could discuss the write-down you took this quarter and a little more detail -- especially since it seems like especially for your commentary that gas fundamentals are actually improving, but it seems like most of the write-down came into gas related segments. I'm wondering if you could just talk a little more about what drove the impairment?

Yes, it's really, we had a triggering event, which caused us to look at the longer term forecasts. And I'll just note that in the Marcellus, primarily due to write-down of goodwill, it was not an impairment of the assets themselves. And I think that's an important thing to recognize. And so it's just with a rapid change in our stock price, the rapid change in the NGL prices, the commodity prices and the concern over the outlook for demand is what caused an examination of the value that we had, the goodwill on the balance sheet as well as in more limited cases the assets themselves.

Okay. And then I guess my second question is the $200 million of operating expense reduction. Is that -- where's that going to come from, I guess? Give me a little more detail on that and...?

Yes, it's all out of the Logistics and Storage segment of the business. And it really -- we capitalized projects and we expensed some projects. And I'll just say that was one of the things that was different between ANDX and MPLX. Certain things that they would have capitalized, we expensed. So, we have certainly a large population of opportunity to spend money on projects that are expensed as opposed to capitalize. And so there's a healthy opportunity there for us to reduce the spending. And so that's what -- that relates to large number of small projects is the way to describe it. All of it was on the Logistics and Storage side of the business.

Next we'll hear from Christine Cho with Barclays. You may go ahead.

I'm not sure if it's too early to thinking about this, but does the pandemic change how you guys are thinking about the MVCs on the legacy products and crude pipes that expire in the 2022 timeframe? What I understand those MVCs were put into place at IPO and were probably more necessary at that time to provide a stable income for the MLP. But MPLX was a lot smaller back then, whereas now it's a lot bigger, more diversified. Should we think that there's always going to be some level of MVCs or is it an option that you just let them roll off because what we're going through is a once in a 100 year event?

Yes, we would expect the contracts to be -- there's an automatic extension provision in the majority of those contracts. So we would expect those to just extend in the ordinary course, the way they're structured today.

Okay. And the automatic renewals are on an annual basis?

No. Five year extensions for the pipeline.

And then, I appreciate your commentary on the Northeast. But can you expand on what sort of conversations you're having with the producers in the Northeast? And how should we think about your exposure given it is a bit more wet gas focused. And while gas prices are seeing a boost, the NGL realizations are still a little bit of a question mark?

Yes, Christine, this is Mike. So, I'll comment first off. Obviously, where crude price and NGL price is, the wet gas is under a little more pressure than is normal. The unknown question is, how quickly does crude price return to a normal place and then how much does the NGL price change as a result of the U.S. refining system running at minimum. So, our expectation is propane prices will be coming up as the situation evolves. I don't know that any of us know really at this point how long the demand recovery will be as a result of the pandemic, shelter-in-place and reopening of the economy is going to play itself out. So, I think that's an unknown. Obviously the boost of natural gas pricing is helping that. And at least in our view, in general, over the longer-term, we still believe overall that, that wet gas economics are better than dry gas economics for the long-term. You get that extra boost. Obviously to your point, in the very short-term, crude prices have gotten pretty low, propane prices have gotten pretty low. Pam has commented on what that sensitivity is for us. But assuming cautious optimism to get the economy going back in the right direction, assuming all the health situation works out fine for everybody and a recovery in the economy and a recovery in GDP, we should see a recovery in NGL prices as well. So, if anything, kind of in a weird way, the pandemic is actually more bullish for the gas/NGL recovery coming out of it once we can see to the point that we actually get out of it. I just think the real unknown is how long does that take and how long do refineries run at minimum. We've stated for MPC that we went to minimum in the back half of March and into April and we've given guidance at MPC for the second quarter that basically says we still expect the U.S. refining system to run at minimum for quite some time to draw down the inventories that were built as a loss in demand. And while that continues to occur, there's less butanes, there's propanes et cetera being produced. So, I guess we’ll all have to watch to see how long it plays itself out. But I think directionally it's good for the gas business in general.

Yes. Christine, I'll just add that, everybody talks about associated gas and how that's helpful for the Northeast on-purpose gas producers. But as associated gas comes down, so does associated NGLs and probably less has been written about that, but there is an expectation that there’ll just be lower NGLs as a result of lower associated gas coming out of the Southwest in particular. So, that could set itself up well for a benefit for NGLs going forward, even though we're not seeing it in the price today.

Our next question will come from Ujjwal Pradhan with Bank of America. Your line is open.

Just wanted to follow-up on the -- your positive free cash flow target in 2021. Does that assume flat distributions from here on and a full recovery of L&S to 2019 levels, and assuming full recovery of refined products demand there, really trying to get at what sort of confidence level in meeting that target with the variables here?

So it's a great question. So obviously, our distribution philosophy is a Board decision. And it's something that we debated very heavily this time because a lot of our competitors have taken advantage, if you want to call it that, to lower that distribution. We, as a Board, talked about it and we felt the right thing for us to do was to keep the distribution but hold off on the growth and leave it in a flat mode. So that's what we decided to do this time. Very much like Christine's question, this is going to be a really interesting year to see how it plays itself out. We don't have a crystal ball, nor does anybody else to know how the pandemic will play itself out, whether there'll be an extended time here. Obviously, the most important thing is, the health and safety of everybody who is involved in this. And as a result, the economy is having a reaction to that. So, it's kind of like the question that was asked earlier, we don't have a strong conviction around that 2021 capital number right at this point, just because we think there's possibilities for it to change, depending on how this plays itself out. So -- but as a general rule, as we looked at the business, assuming full payout of distribution, and assuming getting our capital to the level that we want it to be, that's why we stated we thought that would be achieved in 2021. As you heard from Shneur’s comments, depending on how this plays itself out, and what recovery you have and how the gas production occurs, we could be close to it in 2020. We'll see. So all those dynamics come into play. I'll just leave you with, our view has been that it’s a goal to get there. There's a couple levers that can be pulled. And right now, our position has been we wanted to get our capital down to a level that we think develops, very strong return projects. So hydrating the capital portfolio has been our focus and having a distribution remain flat to where it was before we thought was the right answer for now.

Ujjwal, I’d just like to add that, as we've looked at the market for some time now, there really hasn't been a reward for growing distributions. And at one time, there was a very high correlation between distribution growth and yield. And that relationship is fundamentally broken and a lot of people are choosing to value the midstream in a different way, EV to EBITDA instead of yield oriented measurements. But also just point out that in terms of our payout ratio, I would say that we're at the high end. So 2019, we’ve about 74% of our operating cash flow paid out in the form of distribution. So if you look across the space, whether it's MLPs or C corps, we're right there at the high end. So we don't think that investors in this environment are rewarding or really are looking for distribution growth. They're really more interested in midstream companies that have that fortressed balance sheet, that have the ability to sustain their distributions over a long period of time.

The one thing I would add -- and we've said this many times, investor feedback is very diverse in this area. There are a lot of investors who feel strongly about maintaining the current distribution levels. There are also many who feel it's an opportune time to reduce it. As Pam stated, we are at the high end. We believe it's the right thing for us to be doing at this point. But it's an area that gets discussed with the Board constantly throughout the year.

Got it. Thanks for that, Mike. And maybe a quick follow-up to your comment earlier on the competition that we have seen between associated gas versus dry gas in the Northeast and how it could benefit in the current environment, and especially also your comment about the NGL pricing from here on. What would you expect to be the driver from here to see potential uptick in production growth in the Northeast and increase in G&P volumes in your system in the Northeast in 2020, 2021?

Yes. Again, I think a lot of it is, depends on how the demand side of this pandemic plays itself out across the whole economy. Obviously the situation, prior to it occurring was, people questioning whether the Northeast was going to continue to maintain or grow. Our view was, it was going to at least maintain and grow a little bit. Obviously, that's bolstered now. But I think, the unknown that's still out there and we don't have this crystal ball either is, how does the U.S. economy respond to this. When does it recover back to I'll say normal levels and have the demand side of the equation. Right now is the thing that I think is still the most unknown. Our focus always is, worry about the things we can control, be conscious of the things that we don't control, but at the same time realize that we don't control some of those. So, part of it is for us to be thoughtful and watch as the demand side of this plays itself out.

And let me just add that, another consideration is that the producers themselves have been and remain under a lot of pressure themselves to generate free cash flow and be a returner of capital to investors, and that's been a big focus for the Northeast producers. Those are among the largest that are our customers. And so, I think they're going to continue to live within their cash flow means and maintain or grow their production within their ability to do that. So, that's another factor. Certainly that gets supported with both higher natural gas and NGL prices, gives them the more financial flexibility, but they're also very mindful of their maturities that come up and their financial position as well. So they're taking proactive steps to make sure that they have strong balance sheets. But that's just another consideration to keep in mind as you think about portfolio growth as we go into the future.

And our last question will come from Tristan Richardson with SunTrust. Your line is open.

Appreciate all the commentary, particularly around the sensitivity in L&S. Just a clarifying question there. Pam, the dollar impact you talked about in L&S, is that across all of the sub segments of L&S, assuming MPC were to flow at minimums or is that just the pipeline sub segment where there's the most volumetric exposure?

That is where we have the most volumetric exposure, but we have feathered in the other pieces where we think there is some volume exposure as well. Wherever we have MVCs, that's what we tried to focus on.

Very helpful. Thank you. And then just one follow up to...

This is Mike. I just wanted to add is, what Pam and the team has tried to do is, we generically lump the term MVC across the business and she has given some color on those numbers. But as you can imagine, every individual asset or pipeline is a lot different. It's a whole scorecard of variations. And then you go into Marine, and then you go into terminals, as well as pipeline. So we're trying our best to give as much color as we can. And then Pam and the team have kind of accumulated that all up and rolled it into one number that hopefully will give you the banks of the river as the refining systems at minimum, here's what to expect. As NGL prices move, we've given that guidance, here's what to expect. We've also given some sensitivity around gas, shut-in, et cetera. So, hopefully that answers the question that I know a lot of people have been wondering and we're trying to give you as much color on it as we can.

Really appreciate the complexity involved there. And then I guess just the last follow-up, just around structure. I think the LP is disclosed in the past that the sponsor can reduce or adjust MVCs in certain conditions. I mean I guess just in this current environment, thinking, have any of those conditions been met where the sponsor could sort of unilaterally make adjustments to MVC agreements with the LP. Clearly, the LP and the sponsor are highly aligned, but just in this environment curious about that?

Yes, no, I don't think so. I think that's a little bit of a misnomer in people's minds. I mean I use the football analogy that obviously we're trying to hit the 50 yard line as far as a market price. The MPC people will have one view that says it's skewed to MPLX, the MPLX people have a view that’s skewed to MPC. So I feel very comfortable that we're between the 40 yard lines, hoping our best to hit the 50. So I know that's a risk that some people have questions, but I really don't think that it should get to the discussion that it does get. And then Pam, kind of talked about, the contractual obligation and automatic renewals, et cetera, et cetera. So, MPC, obviously is integrated to MPLX via the distribution coming back. So there's a synergy relationship between MPC and MPLX. But I think sometimes people don't understand as much as it is.

And with that, thank you for joining us today and thank you for your interest in MPLX. Should you have additional questions or would you like clarification on topics discussed this morning, members of our team will be available to take your call. Thank you again. Operator?

That does conclude today's conference. Thank you again for your participation. You may disconnect at this time.