Good day and thank you for standing by. Welcome to the Targa Resources Corp. Q2 2021 earnings conference call. At this time all participants are in listen-and-only mode. After speaker's presentation there will be a question-and-answer session. To ask a question you'll need to press star one on your telephone. Please be advised that this conference call is being recorded and if you require any assistance, please press star zero. I will now hand the conference over to your speaker today, Mr. Sanjay Lad, Vice President of Finance and Investor Relations. Please go ahead.
Thank you, Victor. Good morning, and welcome to the Q2 2021 earnings call for Targa Resources Corp. The Q2 earnings release, along with the Q2 earnings supplement presentation for Targa Resources that accompany our call, are available on our website at targaresources.com in the Investors section. In addition, an updated investor presentation has also been posted to our website. Statements made during this call that might include Targa Resources expectations or predictions should be considered forward-looking statements within the meaning of Section 21E of the Securities Exchange Act of 1934. Actual results could differ materially from those projected in forward-looking statements. For a discussion of factors that could cause actual results to differ, please refer to our latest SEC filings. Our speakers for the call today will be Matt Meloy, Chief Executive Officer, and Jen Kneale, Chief Financial Officer.
Additionally, the following senior management team members will be available for Q&A: Patrick J. McDonie, President, Gathering and Processing, D. Scott Pryor, President, Logistics and Transportation, and Robert M. Muraro, Chief Commercial Officer. With that, I'll now turn the call over to Matt Meloy.
Thanks, Sanjay. Good morning, everyone. We're excited to announce another great quarter at Targa, as our overall business continued to perform well, led by our position in the Permian Basin and our integrated NGL business. As we continue to execute on our key strategic priorities, we are very pleased with our positioning. Taking into consideration our H1 performance and the strength in our business outlook for the H2 of this year, coupled with stronger commodity price fundamentals, we are increasing our estimated 2021 EBITDA to be between $1.9 billion and $2 billion. 2021 EBITDA is now estimated to be 19% higher than last year based on the midpoint of our new guidance range.
Our prioritization of free cash flow for debt reductions mean we reduced our debt balance by $780 million in the H1 of the year, and our consolidated leverage was 3.8 times at the end of the Q2 , within our target range of three to four times, and well ahead of schedule due to our strong performance. This provides us greater flexibility and bolsters Targa's financial position. We now expect to end the year at about 3.5 times leverage with a strong balance sheet and well-positioned to repurchase the DevCo interest in the Q1 of next year. We are also very proud of the efforts of our Targa employees over a difficult last year and a half. Our employees have continued to perform exceptionally well for our customers and have done so with a continued focus on safety, and we are very thankful for their efforts.
Let's now turn to our operational performance and business outlook. Starting in the Permian, Q2 system volumes rebounded quickly following the major winter storm during the Q1 as system inlet volumes increased 15% sequentially. We now expect our 2021 Permian inlet volumes to increase at a high end of our previously disclosed 5%-10% growth over 2020. Our Permian Midland system ran above nameplate capacity for much of the Q2 , and we're pleased to announce our new 200 million cubic feet per day Heim plant is mechanically complete and expected to begin full operations in early September. A special thanks to our operations and engineering teams for safely bringing online Heim well over a month ahead of schedule and under budget.
We expect Heim to commence operations highly utilized, and given our outlook for continued production growth, we announced this morning our plans to move forward with the construction of our new 250 million cubic feet per day Legacy plant, which is expected to begin operations during the Q4 of 2022. Even with the addition of Legacy, there is no change to our 2021 net growth capital spending estimate of between $350 -$450 million. Our current year spend on Legacy is estimated to be about $70 million. In Permian Delaware, completions and activity levels have continued to ramp, and we currently have adequate processing capacity to accommodate our anticipated near to medium-term growth. The stronger outlook across our Permian Basin footprint, coupled with our new plant announcement, will continue to drive incremental volumes through our downstream businesses.
Moving on to the Badlands, we saw sequential increases to our gas and crude volumes during the Q2 . Producers are completing wells, and we continue to have positive producer dialogue. Turning to our central region, gas inlet volumes during the Q2 also rebounded from the Winter Storm and increased 8% sequentially. While the system continues to largely be in decline, we are currently seeing a modest uptick in completions and activity, which could mitigate some of the decline. Shifting to our Logistics and Transportation segment, overall system volumes during the Q2 meaningfully rebounded from the effects of prior quarter's major Winter Storm. Our Grand Prix pipeline continues to perform very well, with total deliveries into Mont Belvieu increasing 14% sequentially. During the Q2 , we transported a record 392,000 barrels per day, and we expect volumes to ramp through the balance of the year.
We also achieved record fractionation volumes at our Mont Belvieu complex, averaging about 644,000 barrels per day during the Q2 , representing an 18% sequential increase. In our LPG export services business at Galena Park, Q2 volumes sequentially increased 20%, averaging 10.3 million barrels per month. While we remain highly contracted, the current higher NGL prices are causing reduced short-term demand for spot opportunities. However, overall, the long-term fundamentals remain strong for LPG exports, and the current strength in propane prices is still a net positive for Targa. Looking ahead, with our leverage already in the target range and on track to be even lower by year-end, we expect to be in a position to return incremental capital to our shareholders in 2022 after repurchasing the DevCo joint venture interest.
We have the ability to return capital to shareholders in a number of different ways: through additional dividends, share repurchases, repayment of preferred equity, and/or continuing to reduce debt. We are currently evaluating, along with our board, the best way to deliver value to shareholders while maintaining our long-term financial flexibility. We will prioritize a strong balance sheet that keeps Targa in a strong financial position across downside scenarios. We expect to articulate more details in February with our 2022 outlook and capital plan for the year. Targa continues to benefit from the strength of our business and our talented employees, and we remain very well-positioned for the long term. With that, I will now turn the call over to Jen.
Thanks, Matt. Targa's adjusted EBITDA for the Q2 was $460 million, as second-quarter volumes across our integrated Permian gathering and processing and logistics and transportation systems meaningfully rebounded from the effects of the winter storm experienced during the Q1 . Q2 EBITDA was sequentially lower, predominantly due to storm-related benefits and seasonal opportunities in our marketing businesses realized during the Q1 , and from higher OpEx from additional volumes moving through our systems and higher G&A. Through the H1 of 2021, Targa has generated free cash flow of $593 million versus $171 million over the same time period in 2020. We significantly hedged for 2021 and continue to add hedges for this year and beyond while still benefiting from higher prices across our unhedged equity volume exposure and prices above fee floors. You can find our usual hedge disclosures in our quarterly earnings supplement presentation.
As Matt mentioned, we are increasing our full-year estimated 2021 adjusted EBITDA to be between $1.9 -$2 billion. Our updated financial estimates assume full-year 2021 WTI crude oil prices average $65 per barrel, NGL prices average $0.70 per gallon, and Henry Hub and Waha natural gas prices average $3.20 and $3.10 per MMBtu. The biggest drivers of our continued performance relative to previous expectations for 2021 are commodity prices, particularly as we benefit from prices above fee floors, also higher volumes, and continued cost management relative to expectations. Inclusive of expected spending this year for the newly announced Legacy plant, our 2021 net growth CapEx estimate remains unchanged at between $350 million and $450 million, and we now estimate net maintenance CapEx to be lower at approximately $120 million. Our continued strong performance means we expect to end 2021 with consolidated leverage around 3.5 times.
This puts us in an excellent position to repurchase our DevCo interest in the Q1 of 2022 while still maintaining consolidated leverage within our target of three to four times. Looking forward, we believe that existing in the lower half of our target consolidated leverage ratio range provides for more flexibility, which is why we are continuing to prioritize free cash flow for debt reduction, particularly in advance of our DevCo repurchase. As we look forward, our balance sheet is well-positioned. We have an excellent liquidity position with no near-term debt maturities. Also, in early June, Fitch issued their inaugural ratings for Targa and assigned us with a BB+ rating. We really appreciate the amount of work that the Fitch team invested to provide that initial rating.
We are now rated by the three leading agencies and are continuing our dialogue with each related to our trajectory towards investment grade, which remains a priority for Targa. Shifting to our focus around sustainability and ESG, we continue to advance our efforts and internal initiatives in this area. We plan to publish our next sustainability report in the fall. In closing, on behalf of all management, we say thank you to our talented Targa team for all that they do. With that, I will turn the call back over to Sanjay.
Thanks, Jen. We kindly ask that you limit to one question and one follow-up for the Q&A lineup if you have additional questions. Victor, will you please open the lines for Q&A?
Of course. As a reminder, to ask a question, you will need to press star one on your telephone, and to withdraw your question, just press the pound key. Once again, that's star one for questions. Our first question comes from the line of Shneur Gershuni from UBS. You may begin.
Hi. Good morning, everyone. Maybe to start off a little bit, just wanted to chat about your guidance. Obviously, it was taken up today and you cited the fact that you expect to be at the higher end of the volume growth range. Just kind of curious, there's been a lot of discussion around increased activity, specifically in the Delaware. I'm curious if that's around your assets and that's what's driving the guidance increase, or is there a potential that if this activity in the Delaware continues to increase, that we could actually see an even higher exit rate for Targa when you close out the year? Just kind of curious what was baked in.
Sure. Hey, good morning, Shneur. We are seeing stronger volumes. We pointed at a high end of our range. I'd say it's in both the Midland and the Delaware. We are seeing, I'd say, higher activity. It's really the dynamic we talked about last call, I'd say, is still for the most part there, which is the larger producers are really staying within what they told us. The smaller and some of the private guys, we are seeing ramp up more. You're seeing a steady increase in the rig count, but not a huge spike up. I think we're just seeing continued strong activity across the board for our producers. Pat, is there anything else you'd want to add to that?
I'd just say that we're seeing activity in both basins. Obviously, Legacy plant announcement. We're seeing continued strong growth on the Midland side of the basin. We have seen more activity in the Delaware Basin, but delineating it just as Matt described, the big guys staying kind of on the programs and more little guy activity. Both sides are growing.
Cool. Definitely appreciate the color there. Maybe to follow up, in terms of the whole simplification approach, you've been pretty consistent in saying that this is really a 2022 event. I think in your prepared remarks today, you talked about DevCo probably happening in Q1 . I imagine you have to give notice, and you'll let us know that ahead of time. If I remember correctly, your Pref steps down in March as well too, which is another component to that. At the same time, you're kind of in this interesting position today where you can actually write that you're going to be at 3.5x leverage by the end of this year. Does that increase your flexibility to be a little bit more opportunistic around buybacks?
Right now, everything's parked to take out the DevCo and maybe work on the Pref later in next year?
Yeah, I'll start, Jen, and then if you want to add in. We did say we are targeting 3.5 through year-end, and that does assume that we're prioritizing our free cash flow to go towards debt reduction. That is our base case plan is to get there, and that just puts us in good position to be able to take out the DevCo in the first part of next year. We do have a share buyback authorized. What you've seen us do this year for the first part is prioritize that free cash flow towards debt reduction. That's my expectation that we'll continue to do that while still having the ability to do share repurchases. We're taking a hard look at that with our board, and we'll lay out what the 2022 capital plan is in February for our free cash flow.
All I'd add, Shneur, is that I think the flexibility as a result of our outperformance this year positions us really nicely to be able to take out the DevCos in the Q1 and still have our leverage within that long-term target range, which is great. As we think about the Pref, we've got a lot of optionality there. It steps down to $105 in mid-March, but that's something that we also could look at taking out ratably over a number of quarters in order to maintain that balance sheet flexibility that we've worked so hard to get.
Great. It sounds like a lot of flexibility here in the outperformance and guidance increase sort of positions you to have a lot of options. Is that kind of the takeaway, guys?
That's right.
Yep, that's right.
Perfect. Thank you very much. Really appreciate the color today.
Okay, thank you.
Our next question comes from the line of John Mackay from Goldman Sachs. You may begin.
Hey, everyone. Good morning. Thanks for the time. Maybe for our first one, I'll just circle back on Shneur's first question on Permian volumes. I'm thinking if we look at where you guys sit right now, you're kind of at the top end of the range or close for the growth guidance, even if you're kind of flat for the next couple of quarters. Just curious to balance that against your comments of activity overall picking up and whether or not that's just some conservatism or you see anything else going on.
Sure. We typically see, especially on the Midland side, a lot of growth as we get into Q2 and into the Q3 . Some of it is seasonal. We see a lot of activity. We see that continuing and sometimes it feels like the activity is more ratable, but the volumes tend to grow more in the Q2 and Q3 . We are seeing that this year, I think, which is part of that. While we do expect some growth as we kind of continue through the back half of the year and into 2022, it may not be at the same rate that we kind of experienced the last few months. Pat, anything?
No, I agree. We're lumpy in the Q2 and Q3 , but we do expect growth through the end of the year. Probably not as lumpy as what we've seen over the last six months.
Okay. That's fair. Thank you. Just on CapEx, H1 was lower than we expected. Looks like the Heim plant's coming in sooner than expected. You guys reduced the maintenance guidance, but not the growth guidance. I'm just curious on what else is filling out that H2 of the year spending, and is that because of more activity, we're seeing more well connects, and that can give us a read in 2022 or anything else going on in there?
I think the biggest piece, John, is the announcement of the Legacy plant. As Matt mentioned in his scripted remarks, that moves essentially $70 million of spending into this year that we otherwise were probably likely going to spend next year. When you think about where we are year to date, we've spent, call it, around $150 million, and then we now have that additional $70 million. The remainder of our expected spending is for additional gathering lines and compression to support the continued growth of our gathering processing footprint, and then some small downstream projects that are consistent with what we've been forecasting previously.
Okay. Thanks. I guess just to clarify that. The Legacy plant, that is still the same one you guys were, I guess, evaluating last quarter, and now it's just formally in the budget. Is that the right way to think about it?
That's right. It's formally board approved now, and the spending has begun on it.
Okay. All right. Thanks for your time. Appreciate it.
Okay. Thank you.
Our next question on the come from the line of Michael Blum from Wells Fargo. You may begin.
Thanks. Good morning, everyone. I wanted to just clarify, just looking at sequentially the marketing, margins were down. Is that just due to the absence of Uri opportunities, or is there something else going on with NGL Marketing? Just wanted to make sure I understood that.
It's really two pieces, Michael, and we talked a little bit about this on our Q1 earnings call. That within the Q1 , on the marketing side, we benefited from both the winter storm, and then there were also some benefits from contango opportunities that we entered into early in the Q2 and late in the Q1 of 2020.
Got it. I wanted to ask about LPG exports. You mentioned perhaps some fewer spot opportunities. In light of just how high propane prices are, do you think in the H2 of the year you're going to see actual cargo cancellations? It just seems like something's got to give.
Yeah, Michael, this is Scott. I would first point to the fact that our export performance was strong in the Q2 . A nice recovery from what we saw in the Q1 , which was impacted by the February winter storm. Certainly, as you pointed to of late and really throughout this year, the increased price on both propane and butane here in the U.S. versus global pricing has impacted some opportunities for spot. I think when you look at it, the international market is choosing at times to look other places as opposed to U.S. Gulf Coast for exports. At times, quite frankly, Targa may choose to not participate at certain pricing levels. As a result of that, I think spot opportunities may be impacted.
As Matt Meloy pointed out, though, higher prices here on propane in the U.S. help us in other areas of our integrated platform. We benefit from that. We have not experienced any cancellations to this point, again, the fundamentals with inventories here in the U.S. are about 20 million barrels behind this time last year. That supports propane prices, which could have an impact on spot opportunities. We're well contracted, and should we see cancellations, obviously, we collect a cancellation fee as a result of that.
Understood. Thank you.
Okay. Thanks, Michael.
Our next question comes from the line of Jeremy Tonet from J.P. Morgan. You may begin.
Hi, good morning.
Hey, good morning.
Just wanted to start off on the credit side here, and we get to similar numbers, you guys being around three and a half times levered at the end of the year, de-levering rapidly into next year, $2 billion being of quite notable size and scale. I'm just curious why the agencies, I guess, haven't been moving a bit quicker towards IG here. It seems like you check all the boxes, those metrics, that leverage is actually better than all the other C Corp peers. Am I missing something here, or is there something else for the agencies?
I think from our perspective, we're in a consistent dialogue with the agencies, and we certainly, I think, share your view, Jeremy. I think part of what they're looking for is just continued sustainable performance and delivering on what we've said we were going to do related to our de-leveraging, related to our continued discipline around CapEx spending and the like. I believe that we already have incredibly strong metrics, and I'm really proud of the organization for getting us in the position that we're in, where we could end this year with leverage around three and a half times. Certainly, agree with you, and I hope that the rating agencies similarly will continue to assess our strong performance thus far this year and really over the last 18 months and will start to take positive credit action.
All we can do is continue to stay in front of them, and I think that we have an excellent dialogue with all three agencies and appreciate the amount of time that they've been willing to spend with us over the last 18 months, too. I do feel like it's just a matter of time.
Got it. Yeah, just wanted to make sure they knew you had the lowest leverage of all C Corp peers because that stood out to us. Maybe moving on here to carbon capture, it seems from the maps that we can tell, some of your processing plants in the Permian are a stone's throw away from some CO2 plants. I'm just wondering, is that something you see in the near future? If there's all this kind of ESG green PE money out there, is there any reason not to invite them into a JV where they put up the capital, you guys put in the assets, and get something going together there that's positive ESG, doesn't cost a lot, for Targa?
Jeremy, we're looking at carbon capture up our processing plants and evaluating what that project could look like. As we go through it, I agree with you, I don't know that there's going to be a shortage of capital, is going to be the issue. Just getting through some of the operational, where we're going to sequester it and permitting and some other things that we're working hard on. You also said in the near term. I think this is also, it is going to take a while, right, for us to figure if we have a viable project here or not. I'd say we're making good progress. As we learn more, I'm becoming increasingly optimistic that there's potential to do something here. It's still going to take some time.
Got it. Hopefully if the Railroad Commission gets primacy there, that things can move a bit quicker. Great to hear things are going in that direction. I'll leave it there. Thank you.
Okay. Thanks, Jeremy.
Our next question comes from the line of Tristan Richardson from Truist Securities. You may begin.
Hey, good morning, guys. Appreciate all the comments. Just a follow-up to an earlier question on capital. In 2022, obviously you guys made very clear priorities in 2022 around leverage and DevCo consolidation and cost of capital management. Just thinking, if we've got a very short list of identified projects and really only half of the Legacy plant spend in 2022, even on the back of increased completion activity, should we think capital could come in further next year than even where you've talked about where the guidance is today for 2021?
Tristan, this is Jen. I think ultimately it will depend on activity levels. We're certainly continuing to see good growth around our systems, particularly on both the Midland side and also the Delaware side and the Permian. We certainly expect continued spending on gathering lines, compression, et cetera. Plus, we'll have the remaining spending of the Legacy plant, and then we'll be having to likely think about the right timing for the next plant in the Midland Basin, just depending on how forecasts look. I think right now we're not in position to give 2022 capital guidance, but I think that my expectation would be that it would be more similar to this year versus we'd see a material drop off year-over-year.
That's helpful. Then just secondly, just curious thoughts on hedging philosophy in 2022. I think this time a year ago, the world was very different, and you guys were very intentional on taking out equity links, just taking it out of the question for 2021. Just thinking in a somewhat more normal world, thoughts on equity links, particularly against the past several years of TRC's big shift to a much more fee-based model.
Yeah. As far as our hedging goes, we are going to want to stay, we call it programmatic hedging. Our target's 75% year one, 50% year two, and then 25% year three. I see us continuing to execute along that programmatic amount and be somewhere around those ranges. You're right, with our leverage lower and with more fee-based, we would have some opportunity to even go inside of that. I think right now where we are is just sticking with that 75/50/25 as approach that's worked for us and something we're likely to hover around for a while.
Great. Matt, thank you.
Okay. Thank you.
Our next question comes from the line of Spiro Dounis from Credit Suisse. You may begin.
Hey, morning team. Two quick follows from me. First one on capital return and tying it back to Jeremy's question around investment grade. Sounds like you guys are on a path there. It's all about execution. Just curious in your discussions with the agencies, have they provided any sort of guiderails for you as you formulate that plan to return capital? Then also imagine you've been getting feedback from investors as you go through this process. Curious what so far has resonated with you as you formulate that plan.
I think clearly our existing investors, potential investors, and then the rating agencies are some of the important constituents where we have to take their points of view into consideration as we work with the board through this fall, really to then be in position to articulate what our go forward strategy on capital allocation will be that, again, as Matt said, we expect to articulate in February, Spiro. I'd say that it's an evolving dialogue. I'd say that we're getting a lot of advice, and I'd say that that advice is varied as one would expect, just depending on what type of investor we're talking to or certainly the rating agencies want to see a more credit positive decision making versus the alternative.
Those are all very important voices, and we are certainly listening to them and then providing our board with that feedback, and that's an important part of the evolving conversation at Targa.
Great. Thanks for that, Jen. Second question, just on asset sales. Obviously not in a position where you need to do anything, but I know at one point you had contemplated selling some non-core assets. Last year, it seems like the M&A market has dramatically improved. Valuations seem to be coming back. Assets are changing hands.
Just curious where that stands and if there's any interest there?
I think you'll continue to see us be opportunistic, Spiro, so to the extent that we think there's an asset or assets that make sense for somebody else to own if they have a lower cost of capital or for other reasons, and that's something that we'll consider. As you said in your opening part of the question, the great part of this is we've got a lot of flexibility, and we don't need to do anything. That means that the bar and the threshold for us willing to sell assets is higher than it certainly was before when we needed to sell assets in order to be able to finance our growth capital.
Got it. That's all I had. Thanks for the time, team.
Okay, thank you.
Our next question comes from the line of Keith Stanley from Wolfe Research. You may begin.
Hi, good morning. I wanted to clarify one thing on return on capital for next year. You listed options of buybacks, dividends, and buying in the preferred equity. I guess, how do you compare buying in the pref versus the other alternatives? You talked a little bit about maybe buying it in gradually. Is it fair to say you have a more patient tone on the pace of taking out the pref than perhaps in past quarters?
I think from our perspective, the TRC pref is a material amount of capital that we need to deploy in order to be able to redeem it. As we look at it is higher cost to us at 9.5%, but we also have a lot of flexibility in terms of the amount of time that we have that we want to redeem it. I think you are hearing from us that our base case assumption right now is that there really isn't a driving reason to have to take it out in the Q1 . In mid-March, when it steps down to 105, we can maintain and even enhance our balance sheet flexibility by being a little bit more deliberate with the TRC pref and taking it out more slowly over time.
That's the base case assumption that we're running, Keith. Of course, that can evolve as we move through this year and into next year as we have more flexibility with increasing free cash flow. That's the current assumption that we're running.
Got it. Thanks. Second question, you've talked about increased activity in the Permian, and I feel like we've heard some mixed things this earning season on that. The one thing I'm wondering, just last year, you had associated gas production meaningfully outpace oil. Are you seeing any changes in that dynamic, or do you think gas NGL production growth from here continues to outpace the oil production growth in the Permian?
No, we see it continuing. As you described, it's exactly right. Obviously, the Delaware is a little oilier than the Midland side of the basin. It depended upon where our overall volume growth could affect it a little bit, but absolutely gassier .
Thank you.
Okay. Thank you.
Our next question comes line of Robert Mosca from Mizuho. You may begin.
Hi, everyone. Thanks for taking my question. One of them was already asked. Just curious, one of your G&P peers in the Bakken seems to be benefiting from rising gas oil ratios and the assets there and in the Permian. We're just curious to hear whether longer term you expect to see a similar sort of GOR trajectory in the Permian as that base matures or whether the Permian is a bit of a different animal in terms of underlying geology. Just curious to hear your thoughts.
Yeah, I think we are benefiting similarly to others as you see higher GOR go up. You have seen that help us out in the Permian, and you've seen our gas performance be even a little bit better than our crude year when you look at this quarter. I think the higher GOR is a tailwind for us across multiple systems.
Okay, thanks. That's all for me.
Okay, thank you.
Once again, that's star one for questions. Our next question will come from the line of Sunil Sibal from Seaport Global. You may begin.
Yeah, hi, good morning, everybody. A couple of questions from me. There has been a fair bit of industry discussion on ethane recovery. I was just curious if you could talk about some trends that you are seeing on your systems and also kind of remind us with regard to your commercial contract with the customers, is those decisions on ethane recovery made at the Targa level or is it primarily at the customers? Especially considering that it seems like you do have some frac capacity and also ability to expand Grand Prix.
Sure, yeah. On ethane recovery, I'd say it varies across our systems for whether producers have elections or we make the election. It varies by contract, by system. For the most part, our assets are in recovery and kind of have been in recovery. That's how most of our assets are operating. You did see if you look, you saw an uptick in South Texas where it was in rejection. Now it's in recovery, so you saw an NGL uplift there. For the most part, the other systems were really already in recovery.
Okay. Second question was related to the margins in the logistics segment. Clearly, there was a bit of a downtick there. I was just curious, on the transportation and services sides, are you seeing any kind of movement in the rates, or that part of the business is fairly steady and most of the dynamics or the changes are on the marketing side of things?
Yeah. Most of our volumes that are going downstream business, whether it's transportation or fractionation, are under long-term contracts. There's not a whole lot of movement in terms of rates there for the volumes that are going through our assets. I think when you look at the unit margin, you just look at the reported numbers. What Jen talked about was we had some marketing gains in the Q1 , so we had some outperformance due to the Winter Storm Uri and some marketing gains, which kind of skewed the unit margins higher. Overall, just run rate business is performing well and are generally under long-term contracts.
Okay, got it. Thank you.
Okay, thank you.
Once again, that's star one for questions. One moment for questions. I'm not showing any further questions in the queue at this moment.
Well, thanks everyone for being on the call this morning, and we appreciate your interest in Targa Resources. The IR team will be available for any follow-up questions you may have. Thank you and have a great day.
This concludes today's conference call. Thank you for participating. You may now disconnect.