Welcome to the MPLX Q1 2023 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. Press star one on your touch-tone phone to enter the queue. 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 1st quarter 2023 earnings conference call. The slides that accompany this call can be found on our website at mplx.com under the Investor tab. Joining me on the call today are Mike Hennigan, Chairman and CEO, John Quaid, CFO, and other members of the executive team. We invite you to read the safe harbor statements and non-GAAP disclaimer on slide 2. It's a reminder that we'll 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 in our filings with the SEC. With that, I'll turn the call over to Mike.
Thanks, Kristina. Good morning. Thank you for joining our call. Earlier today, we reported our Q1 results. Our business continues to grow and delivered adjusted EBITDA of $1.5 billion, an increase of 9% year-over-year and a new quarterly record for the partnership. Distributable cash flow of nearly $1.3 billion was up 5% year-over-year. Turning to the macro environment, while natural gas prices have come down recently, our long-term production outlook in our key regions remains largely unchanged. In our largest basin, the Marcellus, the cost to deliver for our key producer customers is still below the current prices. In the Permian and Bakken, our production outlook is unchanged as crude prices are strong and prices for associated gas do not significantly impact producer activity in these basins.
This quarter, we advanced our growth projects, which are anchored in the Marcellus, Permian, and Bakken basins. We expect these disciplined investments in high return projects, along with our focus on cost and portfolio optimization, continue to drive cash flow growth. While our capital outlook is focused on our current LNS and G&P asset base, we are participating in three publicly announced alliances focused on CCUS and hydrogen technologies.
We will continue to evaluate low carbon opportunities where we can leverage technologies that are complementary with our asset footprint and expertise. We remain optimistic about our opportunities in 2023 and are focused on executing the strategic priorities of strict capital discipline, fostering a low-cost culture, optimizing our asset portfolio, all of which are foundational to the growth of MPLX's cash flows. Now let me turn the call over to John to discuss our growth as well as our operational and financial results for the quarter.
Thanks, Mike. Looking back over the last several years, our successful execution of the foundational strategic priorities Mike just referenced has resulted in a 6.8% compound annual growth rate for our DCF. As you can see on this slide, our growth is not linear and tends to come in stairsteps as we develop and bring projects online. Last quarter, we announced a 2023 capital outlook of $950 million, including $800 million of growth capital and $150 million of maintenance capital. Across both segments, we are focused on projects targeted at expansion or debottlenecking of existing assets to meet customer demand. In the LNS segment, our joint venture projects in the Permian are progressing.
We see strong demand for the Whistler natural gas pipeline and its expansion to 2.5 billion cubic feet per day, which remains on schedule for completion this September. We also expect volumes on the Wink to Webster crude pipeline to ramp over this year and the next two years as the pipeline continues to place segments into service. As a reminder, these projects are largely financed at the joint venture level, and the related capital is not reflected in our capital spending or capital outlook. In the G&P segment, Tornado II, our fifth 200 million cubic feet per day gas processing plant in the Permian, came online in the Q4 of last year and is already operating near capacity ahead of our mid-year goal.
We are also progressing Preakness II, our sixth plant in the Permian, and a plant in the Marcellus, Harmon Creek II. Both of these gas processing plants are expected to be online in the H1 of 2024. Slide six outlines the Q1 operational and financial performance highlights for our logistics and storage segment. The LNS segment reported record results with its first $1 billion adjusted EBITDA quarter. LNS segment adjusted EBITDA increased $122 million when compared to Q1 2022. The increased results were primarily driven by growth in throughputs and higher rates across our LNS business lines. Total pipeline volumes were up 6% year-over-year, primarily due to growth in crude oil throughputs associated with expansion and debottlenecking activities and impacts associated with Marathon's refinery turnarounds.
Terminal volumes were similarly up 5%. Moving to our gathering and processing segment on slide 7, G&P segment adjusted EBITDA increased $4 million compared to Q1 2022, as higher throughput fees and volumes were offset by lower natural gas liquids prices. While our G&P segment is largely a fee-based business, we do have some direct sensitivity to natural gas liquids prices. As a rough rule of thumb, our annual results are impacted by about $20 million for every $0.05 per gallon change in NGL prices. NGL prices average $0.77 per gallon for the quarter as compared to $1.15 in the Q1 of 2022, resulting in roughly a $40 million unfavorable effect versus the prior year period. For the quarter, total gathered volumes were up 21% year-over-year due to increased production in the Utica and the Permian.
Processing volumes were up 4% year-over-year, primarily from higher volumes in the Permian, driven by increased customer demand and our investments in processing capacity. Focusing in on the Marcellus, our largest basin of G&P operations, we saw year-over-year increases for gathering and fractionation volumes driven by increased customer demand and our investments in fractionation capacity. Moving to our Q1 financial highlights on slide 8, total adjusted EBITDA of $1.5 billion was up 9% from the prior year, while distributable cash flow of $1.3 billion increased 5%. The lower year-over-year DCF growth was partly due to timing of maintenance capital expenditures, which were $30 million higher than the prior year. While we expect annual project-related expenses to be flat with the prior year, these projects are not performed ratably over the year.
As discussed last quarter, the Q1 is typically our lowest quarter for project-related expenses. As we look to the Q2, we anticipate these expenses will increase sequentially, as they have done in prior years. MPLX declared a Q1 distribution of $0.775 per unit, resulting in distribution coverage ratio of 1.6x for the quarter. During the quarter, we issued $1.6 billion in senior notes, and we redeemed $600 million of outstanding Series B preferred units and $1 billion of senior notes scheduled to mature in July.
MPLX ended the quarter with total debt of around $21 billion and a debt-to-EBITDA ratio of 3.5x . Our leverage ratio has decreased over the last few years as our earnings have grown, while our absolute debt level has remained relatively constant, providing the partnership with financial flexibility. Now let me hand it back to Mike for some final thoughts.
Thanks, John. In closing, MPLX's growth strategy supports our commitment to return capital to unitholders. MPLX remains a strategic part of MPC's portfolio, supported by the over $2 billion MPC receives annually from MPLX distributions. As MPLX pursues its growth opportunities, we expect the value of this strategic relationship will continue to be enhanced. Our business continues to grow and generate strong cash flows. By advancing our high return growth projects anchored in the Marcellus, Permian, and Bakken basins, along with our focus on cost and portfolio optimization, we expect to continue to grow our cash flows, allowing us to reinvest in the business and return capital to unitholders. For 2023, we expect the distribution to be our primary tool to return capital to unitholders. Now let me turn the call back over to Kristina.
Thanks, Mike. 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'll now open the call to questions. Sheila?
Thank you. We will now begin the question-and-answer session. If you have a question, please press star then one on your touch tone phone. If you wish to be removed from the queue, please press star then two. If you are using a speakerphone, you may need to pick up the handset first before pressing the numbers. Once again, if you have a question, please press star then one on your touch tone phone. Our first question will come from Jeremy Tonet with JP Morgan. Your line is open.
Hi, good morning.
Morning, Jeremy.
Just wanted to pick up with some of your later comments there as it relates to capital allocation. I was just wondering if you could update us, I guess, on how your thoughts on capital allocation have evolved over time, where you see it today and what factors have driven that change or evolution of views over time.
Hey, Jeremy, it's John. A great question. I'll take that and then let Mike comment as well. You know, certainly as we look at where we are now, right, we're as we said last quarter, we're focused on the distribution. You know, we certainly over the last few years have had opportunities on the repurchase side, and we'll continue to look at that. you know, we're perhaps more opportunistic than we have been in the past, as we commented last quarter.
Even if you think back, we even tried a supplemental at one point. I think we've tried that and maybe, you know, got some reaction on that one that maybe is not still a tool for us, but not our primary focus. As we look at where we are now, again, looking back at last year's numbers, $6 billion of EBITDA, $5 billion of DCF, $4 billion of free cash flow, paying out $3 billion in distribution, $1 billion left over. We're sitting in a strong position.
Balance sheet is strong, gives us that financial flexibility to think about capital allocation across the business. As you see, we continue to focus on strict capital discipline. You know, we haven't changed our outlook of $800 million of growth spending for the year. Really, I think as we've pivoted here recently, we see the distribution as our best opportunity to drive value for all unit holders while still supplementing that with opportunistic unit repurchases.
Got it. Just curious, I guess, on the driver there and the shift towards more distribution growth over unit repurchases, if you could provide a little bit more color on what were the drivers in that thought process?
Yeah, I mean, I think as I was saying, Jeremy, when we looked at, the space, our opportunity, you think even through COVID and, maybe if you want to call it the COVID recession, we continued to grow the cash flow of the partnership and have built up coverage, as we pulled back, you know, we pulled back on our distribution, others may have cut. Now that we look at where we are, we certainly see that tool as the one that best gives us the best opportunity to solidify that value, for all unit holders. You know, it certainly has progressed over time.
I mean, it's one thing, if you think about the over $1 billion of repurchases we did, we did that at an average unit price of $29 a unit, right? We're sitting at about $35 today. You know, we always continue to look at where those levers are. Again, I think over time, as the options have evolved, right now we see the best opportunity to drive value in the distribution.
Jeremy, it's Mike. I'm going to add that in the quarter, there was less volatility than normal in the unit price. You know, we still have buybacks on the tool belt, but as John said, and we said in our prepared remarks, we want investors to know we're committed to growing cash flows, and as a result, we're committed to growing our base distribution. You know, we still have everything on the tool belt, but we're going to lean harder in general towards distributions to show investors we're continuing to grow the cash flows.
Got it. That's helpful. Just one last one, if I could. Mike, I know that MPLX isn't a forward guidance company, but last quarter you provided a bit more color as far as mid-single digit growth potential. I was just wondering, you know, strong result this quarter, is that repeatable? Is that part of that mid-single digit growth that you were talking about? It seems like street expectations in future years still aren't at that level. Just wondering how we should think about that or what people might be missing.
Yeah. Thanks, Jeremy. It's a good question, you know, a lot of people have written it in a certain fashion. What I meant was a general outlook of the business. I t will be stairstepped, you know, particularly on the natural gas side of our business. Let me just give you the facts, then I'll come back to the comment. The facts is our distributable cash flow grew 6% in 2020 despite COVID. It grew 11% in 2021. It grew 4% in 2022. If you look at that 3-year CAGR, it was 6.8%. You can see a little bit of the stairstep.
You know, it's up 6, up 11, up 4, so it's bouncing around a little bit. Gotten a lot of questions about, you know, how we view our growth. I was just trying to give, you know, what I consider just a general outlook of the business. If you look at the last three years, I think that supports the statement. I'm hoping that helps. Thanks for commenting that we're not generally a guidance company, but just trying to give you a little bit better feel for how we think about the business and the growth of the cash flows.
Got it. That's helpful. I'll leave it there. Thanks.
You're welcome, Jeremy. Thank you.
Thanks, Jeremy.
Thank you. Our next question will come from Brian Reynolds with UBS. Your line is open.
Hi. Good morning, everyone. Maybe just to follow up quickly on, you know, capital allocation priorities and the growth CapEx. You know, you've discussed, you know, the low multiple type build projects already in the backlog b ut curious if you can just give us maybe a forward 24, 25 outlook towards, you know, CapEx. Are there, you know, attractive growth projects that MPLX is looking at that could, you know, potentially impact, you know, share buyback or unit buybacks in support of that DPU growth over the long term? Thanks.
Yeah. Hey, Brian. It's John. Good morning. You know, I don't know that we're ready to provide 2024, 2025 guidance at this point, right? You have seen us the last few years talk about a zone for where we're looking, you know, what that piece of our capital allocation looks like. I don't know that we're anticipating a major change there, but it probably a little bit early to talk about 2024, 2025 at this point.
I guess just as a quick follow-up, is it fair to say that the projects would be pretty similar to the current slate of projects, or is there anything else that MPLX is looking at?
Yeah, I mean, if you think about some of the big ones I talked about, we'll still be spending some money on in 2024 to get them up and running. You know, it's been our playbook, right? You know, we continue to look at opportunities, and the best ones we see are across our footprint in the basins and areas where we've got strength on the G&P side or strong tie-ins with MPC as well. I think we're going to continue to look at those opportunities. T hat's what we've got in the pipeline right now. You know, it could always change, but that's where we are right now.
Brian, it's Mike. I'm just going to add, you know, our asset base is big enough. You know, we're roughly, you know, $6 billion of EBIT at this point. You know, our asset base is large enough that we get these organic growth opportunities that are not headliners, but they provide, you know, meaningful returns. Like I just answered to Jeremy's question, when you look at, you know, growing DCF, you know, six eleven four over the last three years or about a 7% CAGR, it shows hopefully it shows the market that, you know, we have opportunities. We're continuing to grow the cash flows, albeit not these big headliner type projects, just a lot of smaller, higher return projects, which we think are, you know, easily executed and just drive right to the bottom line quickly.
You know, to your question, yeah, there's a, you know, a backlog of things that we're looking at that are, that are similar. You know, we'll continue to grow the asset base and bolt on to all the places that we see where growth can be. It's primarily in those basins that we've talked about as the larger ones. We still have smaller projects occurring in those other basins as well. You know, if we spend the capital that we're thinking about, you know, over time, we think we're going to continue to grow those cash flows just the way we've described.
Great. Thanks. Just as my one follow-up, you know, we have seen some CapEx inflation on some Permian related long-haul projects. Could you just give us an update on your current, you know, budget versus actual so far on just Permian nat gas projects? Are they expected to come online on time and on budget? Thanks.
Yeah. I'll let Shawn take a stab at that one.
Thanks for the question. This is Shawn. One of the, you know, we really on Whistler, we continue to see strong demand for that, you know, contracted capacity there and are pleased with that. The expansion that we've announced previously that should come online in September of this year really is on plan and on budget. We're pleased with that. Again, the dynamics or fundamentals for the Permian gas takeaway are still strong. Thanks for the question.
Great. Really appreciate it. Have a great rest of your day.
You're welcome, Brian. Thank you.
Thank you. Our next question will come from Keith Stanley with Wolfe Research. Your line is open.
Hi. Good morning. There was a reference to portfolio optimization as a focus, I think a few times on the prepared remarks and in the release. Any updates there? I assume you're alluding to some of the less core assets and regions. Are you more optimistic on finding opportunities for portfolio optimization?
Good morning, Keith. It's John. Thanks for the question. I think there again, it may be similar to Mike's comments on the capital side. It's probably more little singles and doubles. We had some maybe even at a lower level than our non-core basins. We've had some asset sales here and there, if you look back at our results over the last year or so. You know, finding maybe terminals that maybe fit better in somebody's portfolio than ours.
For example, on the G&P side, we might have some natural gas supply lines for utilities that the utilities might be interested. It's probably been smaller things like that that we've been doing that we probably don't raise to a level where we talk about those specific items in our materials. Again, those continue to, you know, drive the cash flow performance of the portfolio. I'd say on the basins, we continue to look there, but really don't have any pressing or immediate updates on that right now.
Great. Thanks. Separate question, just you highlighted there's still $1 billion of excess free cash flow basically after distributions and clearly pointing to more distribution growth as a focus. Aside from distributions, do you look at other potential options? I guess I'm asking specifically, are acquisitions more likely in the mix, just that you have a lot of this financial cushion and capacity?
Yeah. Thanks for that. I'll start, and then I'll let Mike comment as well. I mean, certainly we have the company financially in a position where if the right opportunity with the right type of high-quality assets that fits into our strategy and our footprint and has the right risk-adjusted return, right? If we hit all those criteria and some others, you know, we've got the partnership in a position where, you know, we can take advantage of those. As I think you've heard us say over a number of quarterly calls, we're pretty strict in how we look at that. It just tends to be more challenging to get the returns on those type of projects versus maybe the opportunities we have organically within our own system in the places where we operate.
Yeah, Keith, I'm going to add to what John just said at the end, cause that's really the key. In order for us to look at something else, it's got to hurdle what we can do on our own. We've just had such a good track record of finding, you know, higher return projects that, you know, we haven't reached out to some of these others. We continue to look at a lot of things. I think people are wondering if we're looking at different opportunities. You know, we are. We have a whole group that does that.
At the end of the day, we compare it to what we have as our plan that we have total control over. You know, as you know, in the M&A market, we don't have control of that. We compare it to what we have internally. If there's an opportunity, you know, we're not opposed to pursuing it. We do have, you know, the words we use is strict capital discipline and believe in getting really strong returns with the capital that we invest.
Sheila, are you still there?
I am still here. Thank you.
Let's take the next question.
Absolutely. Our next question comes from Theresa Chen with Barclays. Your line is open.
Good morning. I'd love to get a sense of how volumes are trending across your G&P footprint, just in light of lower natural gas prices. Going back to your comment earlier, Mike, about production economics still being intact, what are you hearing on the ground from your customers?
Yeah. Thanks, Theresa. I'm going to let Greg start and then I'll come in after that.
Theresa, this is Greg. As Mike mentioned earlier, you know, our largest area, which is Appalachia, particularly Marcellus, is one of the lowest cost production basins. If you look at, if you look at the macro drivers for what determines activity, the production cost level versus gas price, the amount of affirmed transportation capacity commitments by various producers and then hedging activity. I think, you know, particularly in the Marcellus, the boxes are checked there for most of the producers. If there's one thing we see, it's probably a shift, you know, the potential for a shift from lean gas, non-processable gas into rich gas basins.
Definitely if you rank the basins, the crude basins are obviously the most attractive with good crude pricing levels versus gas. That activity is going to continue regardless of the natural gas prices. Waha is a good example of that. Negative prices at times, but good crude prices still spurring growth. You know, in general, we see more likely more shift to ethane recovery versus rejection because those recovery spreads for fractionating ethane are positive. We think that there should be a continued potential shift over the rich gas areas from maybe more dry gas areas, which is very supportive of our large processing and both ethane, de-ethanization and C3+ fractionation basin in the Northeast in particular.
Theresa, it's Mike. I'll just add, you know, I think Greg hit it on the head. You know, as you see fluctuations in gas prices, and obviously everybody's seen them over the last year or so, you know, the rigs move around depending on wet versus dry, depending on the region and whether it has takeaway capacity, et cetera. Overall, we've been bullish natural gas, and we continue to be that into the future, particularly into a low carbon future. There's going to be some stairsteps that, you know, play itself out.
You know, takeaway capacity from the U.S. will change with more LNG, you know, next year and beyond. You know, that's one thing that'll happen. As, you know, hopefully permitting reform gets a little bit more advanced, you'll see some projects advance on a more timely fashion. In general, I think we're still believing that the U.S. natural gas market is advantaged, globally, and it'll be an area of growth for us for some time.
Thank you. In terms of the seasonality in your project-related expenses, and the anticipated increase quarter-over-quarter heading into Q2, is there a magnitude you can point to on how we should frame that?
Yeah. Hey, Theresa, it's John. Thanks for the question. Yeah, I mean, again, I think it's something that flows similar year to year. If you look at last year, Q1 to Q2, those costs were probably up about $30 million. We could maybe see something a little bit higher this year, but at least that gives you a little bit of a sense of the magnitude, and hopefully that's helpful.
Thank you.
Thank you.
You're welcome, Theresa.
You're welcome. Sorry.
Our next question will come from Michael Blum with Wells Fargo. Your line is open.
Hey, thanks. Good morning, everyone. Just had a question on the LNS segment. You had really strong volumes on the crude and terminal side. I'm just wondering, is this a sustainable level, or is there anything specific going on this quarter to point to? Thanks.
Morning, Michael. It's John. Thanks for the question. I think there's a couple of things there. One, as we highlighted, there's some of that effect that's driven off of MPC refinery turnarounds. The things to remember is our pipelines of crude into the refineries and product out, they aren't the same level at every refinery. Depending on which refinery is up or down, you may or may not see the effect, for example, on the crude side, if the crude coming into that refinery is on somebody else's pipeline. There's a little bit of that effect in there. Again, too, I mean, one other thing that's driving that growth is also our pipelines around the crude gathering business as we continue to grow that, you know, primarily in the Permian as well. That's baked into those numbers. It's the mix of those two things that's driving the relative increase.
Got it. Thanks. That's all I had today. Thank you very much.
Thanks, Michael.
Thank you. Once again, if you would like to ask a question at this time, you can press star one and record your name when prompted. Our next question will come from Doug Irwin with Citi. Your line is open.
Hey, thanks for the question. Maybe to follow up on that last comment just around some of the turnaround schedules. I think if you look at maintenance CapEx for 1Q, you're already about a third of the way through the annual guidance numbers here. Just curious if there's any heavy maintenance activity to call out in the quarter and how we should be thinking about the rest of the year, given that the MPC's turnarounds tend to be more back-half weighted?
Yeah. No, no, great question, Doug. Part of what's happening on the MPLX side with our maintenance capital, we do have some timing things this quarter. Again, we haven't changed our outlook of $150 million for the year, a little bit higher this quarter at $44 million, driven by a couple of major items. One, on the marine side of the business, when we replace assets, barges, vessels, but we maintain at the same level of total assets, we treat that and report that as maintenance capital because we're not really growing our EBITDA, we're maintaining it.
We did have some asset replacements, excuse me, on the marine side that are just specific to that quarter that we don't have planned for the rest of the year. We also had some work around a compressor station in Oklahoma, some repairs we were doing, and that work was completed in the quarter, and we don't see a significant item like that over the balance of the year. Again, it's more the maintenance on our assets, not necessarily tied to MPC's turnaround schedule.
Hey, Doug, it's Mike. Just for clarity, MPC's schedule is front half-weighted in 2023, you know, mainly in Q1 and Q2. Last year, it was back half-weighted, mainly Q3 and Q4. Just to give you that color on MPC as well.
Okay, great. That's helpful. Maybe just another follow-up on Brian's earlier question about this Permian gas takeaway. We've seen some peers file additional permits here recently for Permian Pipelines, which seems to signal demand for more capacity beyond what's already been announced. I'm just curious to get your broader thoughts on Permian gas takeaway and how you see these dynamics playing out over the next few years.
Hey, Doug, thanks for the question. This is Shawn. Hey, you know, as I mentioned, we're continuing to be the gas takeaway. The demand continues to be strong. Our Whistler investment, you know, is paying out. Again, we look forward to the expansion of Whistler and Matterhorn. We continue looking at future opportunities in that area. We see that, you know, that strong demand as Greg and Mike have said, base to get to the crude. We're pleased with where we're at and look forward to the future opportunities that we see.
Great. That's all for me. Thanks for the time.
Thanks, Doug.
Thank you. Our next question comes from Neal Dingmann with Truist Securities. Your line is open.
Morning, gentlemen. My first question is just on the potential of the Marcellus expansion and then bottleneck. I know you've spoken in the past. I believe I'm just curious on, number one, the amount of space that you still have there on the existing processing plants, and you know, just what the thoughts are on investing capital there in the near term, given gas prices.
Neal, this is Greg. In terms of the capacity, you know, we process over 6 billion cubic feet a day of gas in Appalachia. Our utilization has continued to be in the high 80%-90% range over the last few years. So we see some producers not continuing to drill to maintain levels. Some are growing. Generally, though, it's a flat to slight growth in the processed volume area, but also drives fractionation. You know, as the rigs shift to dry gas, you typically see much higher volumes on IPs with dry gas than you do with rich, it opens up more takeaway capacity.
As we also see more ethane recovery, it opens up takeaway capacity on the residue lines. You know, in terms of individual producers, we'll continue to see growth. You know, some of our, you know, recently announced Harmon Creek II project expansion is a sign of that. On a producer-by-producer basis, there is growth in some areas, essentially with room made for that capacity by declines in others.
Very good. You touched on this, I just want to make sure I understand just on what you've most recently seen on the MPC refinery runs. I'm just wondering, any change on expected activity or utilization for you all?
Yeah. Hey, Neal, it's Shawn. It's a great question, and I think sometimes the challenge for folks to understand what sensitivity we have or frankly don't have, the changes in MPC's utilization. It's really driven off of, you know, the MVCs, and in some cases, right, some of our assets are fee for capacity. We're getting paid to run and operate those assets regardless of utilization levels. While we do have some sensitivity to MPC's refinery utilization, I think it's maybe a little bit less than folks might think it is.
Great call. Thanks, Shawn.
You bet. Thank you. Thanks for the question.
Thank you. Our last question will come from Neel Mitra with Bank of America. Your line is open.
Hi. Thanks for taking my question. Firstly, I wanted to ask what inflation adders you have in place, and maybe, how much they are. Are they FERC-related, and where do they reside? Are they in LNS primarily or also in the G&P segment? Finally, when we would expect the timing of inflation adders to impact earnings?
Hey, Neel, thanks for the question. This is Shawn. You know, as you know, FERC is, you know, they're going through their process now. It's very public, very transparent, you know, to determine what that index rate is for the entire industry. Once we should hear in the next couple weeks. Once we get that, we'll go through our process based on their guidance system by system to make sure we can implement it, and then we'll post our tariff at the end of May with implementation in July. You know, I don't want to get ahead of ourselves, but really it's we'll know more in a month where we're at, but we're just following their guidance as they move through their very public process. Hopefully that helps Neel. Thanks for the question.
Yeah. Hey, Neal, it's John. Let me just add generally, right? Shawn's speaking to the pipeline portion of our business. We have other inflation escalators. Some are fixed, some are linked to CPI, some are linked to other indexes. Some of those are effective January 1, some are effective July 1. You know, Shawn's speaking specifically to the pipelines, but we do see our contracts do have those escalators in across other portions of the LNS business, and we even see it a little bit on the G&P business as well. Again, just generally giving you, but it's a mix. Some are fixed, some are, you know, indexed to certain items, and again, they have different effective dates as well.
Got it. I appreciate the color. My follow-up question, your equity interest in the Whistler expansion and also Matterhorn Express, one of your peers talked about their expansion being delayed a couple of months. I was just wondering if you could comment on if there's any potential delays or bottlenecks for your projects going forward right now, or if you see any constraints?
Hey, hey, this is Shawn again. We are not seeing on our Whistler expansion, again, we're not seeing any delays, and we're on plan and on budget.
Great. Appreciate the color. Thank you.
Thank you.
Thanks, Neal.
With that, thank you for joining us today, and thank you for your interest in MPLX. Should you have additional questions or would like clarification on any of the topics discussed this morning, members of the investor relations teams are available to take your calls. Have a great day, everyone.
Thank you. That does conclude today's conference. Thank you for participating. You may disconnect at this time.