Good day, everyone, and thank you for being here. Welcome to the Targa Resources Corporation Second Quarter 2025 Earnings Webcast and Presentation. I would like to hand the conference over to Mr. Tristan Richardson, Vice President of Investor Relations. Sir, please go ahead.

Thank you, Howard. Good morning, and welcome to the second Quarter 2025 Earnings Call for Targa Resources Corp. The second quarter earnings release along with a supplement presentation that accompanying our call are available on our website at targaresources.com. Additionally, an updated investor presentation has also been posted to our website. Statements made during this call that might include Targa's 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; Jen Kneale, President; and Will Byers, Chief Financial Officer. Additionally, members of Targa's senior management will be available for Q&A, including Pat McDonie, President, Gathering and Processing; Scott Pryor, President, Logistics and Transportation; Bobby Muraro, Chief Commercial Officer; and Ben Branstetter, Senior Vice President, Downstream. I'll now turn the call over to Matt.

Thanks, Tristan, and good morning. I would like to begin by announcing that after 35 years with Targa and its predecessor company, Scott Pryor, our President of Logistics and Transportation, has shared with us his intent to retire effective March 1, 2026. Scott has been a critical part of the Targa team and his leadership, work ethic, dedication, integrity and focus on serving our customers has made it a pleasure to work alongside Scott. On behalf of our Board, the leadership team, all of Targa's employees and our customers, I'd like to thank you, Scott. Following Scott's retirement, Ben Branstetter will succeed Scott as President of Logistics and Transportation. Ben has been with Targa for the past 8 years in various leadership roles across corporate development and our downstream group. Scott and Ben have worked closely together for years and will work together over the next many months in transition, and we look forward to Ben's continued contribution to Targa in his new role. Turning to the second quarter. We reported strong results with record Permian volumes, record NGL transportation volumes and continued execution across our footprint, setting us up well for the balance of the year and providing a lot of momentum looking ahead. We saw a strong ramp in volumes in the second quarter as gas on our Permian system increased by about a processing plant worth of volumes during the quarter, up about 270 million cubic feet per day. We are seeing that strength continue. In July, our volumes were up another 250 million cubic feet per day, meaning we added a plant worth of gas in the second quarter and another plant worth of gas in July, and we are seeing that strength continue so far in August. There has been movement in the broader Permian rig count this year, which has been a focus for investors. Over the last 4 months, while the Permian rig count has softened, the number of rigs on our system is largely unchanged. While there is a lot of noise and volatility in the macro environment, ongoing discussions with our producers point to continued strong growth on our system for the remainder of 2025 and into 2026 and beyond. Given the strong ramp in volumes we're seeing in our expectations for the remainder of the year, our outlook for 2026 volume growth is as strong now as it was at the beginning of the year with the potential for it to be stronger by the time we exit this year. We have also added some new material to our investor presentation, which lends support for our continued growth outlook. We have highlighted some factors that demonstrate Targa's differentiated growth profile. Over the past 5 years, Permian gas production has grown at a higher rate than crude production due to the general increase in gas to oil ratios across the basin over time. While year-over-year growth in crude production from the Permian has averaged 8% per year over the past 5 years, associated gas growth has averaged 13% per year and Targa's volume growth has outperformed crude and gas production over that time frame. Our year-over-year volume growth has averaged 17%, 4% higher than associated gas and 9% higher than crude per year. Looking forward, third-party forecasts call for 7% growth in Permian associated gas over the next 5 years. With this strong outlook, coupled with Targa's footprint across the best rock in the basin and world-class producers, we are well-positioned for meaningful growth over the long term. There are a lot of tailwinds for Targa. We move a lot of natural gas to end markets, and the demand for natural gas is expected to continue to increase. We transport and fractionate a lot of natural gas liquids to domestic and international end markets, and the demand for NGLs is expected to continue to increase. Our customers across our value chain are very good at what they do, and we think will continue to create meaningful growth opportunities for our company. Our conviction is demonstrated by $324 million of common share repurchases during the second quarter across a volatile quarter. Our focus continues to be on increasing adjusted EBITDA and increasing common dividend per share and declining share count while maintaining our strong investment-grade balance sheet. We believe that our premier Permian asset footprint, integrated wellhead to water system and strong financial position will allow us to continue to invest in integrated growth opportunities, generate attractive returns and return increasing capital to our shareholders over the long term. Before I turn the call over to Jen to discuss operations in more detail, I would like to thank the Targa team for their continued focus on safety and execution while continuing to provide best-in-class service and reliability to our customers.

Thanks, Matt. Good morning, everyone. Let's talk about our operational results in more detail. Starting in the Permian, our natural gas inlet volumes averaged a record 6.3 billion cubic feet per day in the second quarter, an increase of 11% versus a year ago and a strong rebound from the first quarter, which was impacted by severe weather events. In the Permian Midland, our new Pembrook 2 plant is currently in start-up ahead of schedule and much needed as our Midland system continues to run at very high utilization. Our East Pembrook and East driver plants remain on track to begin operations in the second quarter and third quarter of 2026. In Permian Delaware, our Bull run 2 plant is ahead of schedule and is now expected to begin operations in the fourth quarter of 2025. Our Falcon II plant remains on track to begin operations in the second quarter of 2026. We expect our processing infrastructure currently under construction will be much needed at startup. Lastly, in the Delaware, we recently completed our seventh AGI well further increasing our leading gas treating capabilities across the basin. Looking out further, we are ordering long lead items for additional Permian plants as we prepare for growth in 2027 and beyond. As production continues to grow, Targa is increasingly moving more and more natural gas for our customers across the Midland and Delaware basins. To further enhance connectivity and reliability, we are announcing an extension of our Bull Run natural gas pipeline system in the Delaware Basin. The 43-mile, 42-inch intrastate natural gas pipeline extension of Bull Run will enhance gas takeaway by increasing connectivity and between our Permian Delaware system and the Waha Hub. The extension will add further flow assurance for our customers across the Delaware and increase access to important residue markets. It is scheduled to be in service in the first quarter of 2027. On the Blackcomb and Traverse natural gas pipelines, where we have a 17.5% equity interest, Blackcomb remains on track and is fully subscribed. The planned capacity of Traverse was recently upsized to 2.5 billion cubic feet per day from 1.75 billion cubic feet per day based on strong customer demand. Shifting to our Logistics and Transportation segment, Targa's NGL pipeline transportation volumes averaged a record 961,000 barrels per day, and fractionation volumes averaged 969,000 barrels per day during the second quarter. Our fractionation volumes were meaningfully impacted by our planned turnaround at our fractionation complex in Mont Belvieu, which reduced our capacity for two-thirds of the second quarter. With the turnaround complete in early June and increasing G&P supply, our fractionation volumes are now more than 1 million barrels per day. Given the anticipated growth in our Permian G&P business and corresponding announced plan additions, our outlook for NGL supply growth on our system remains strong. Looking at our downstream projects currently underway, Delaware Express, our intrabasin NGL pipeline expansion is ahead of schedule and is now expected to be complete in the second quarter of 2026. Our next fractionator in Mont Belvieu, Train 11 is also ahead of schedule and is expected to be complete in the second quarter of 2026, and Train 12 remains on track for the first quarter of 2027. Turning to our LPG export business at Galena Park, our loadings averaged 12.8 million barrels per month during the second quarter. Despite shifting trade policy and a lot of macro headlines, our docks remained effectively full, and we are seeing continued strength in cargo loadings. Our LPG export debottleneck expansion is expected to be in service in the fourth quarter and we remain on track with our larger LPG export expansion, which will increase our loading capacity to approximately 19 million barrels per month and is scheduled to be online in the third quarter of 2027. To build on Matt's earlier comments, even with commodity price volatility and headlines around global trade, our results highlight our resilient business model. We are well positioned operationally and believe that our leading customer service-driven wellhead-to-water strategy puts us in excellent position to continue to execute for our shareholders.

Thanks, Jen. Targa has reported adjusted EBITDA for the second quarter was $1.163 billion, an 18% increase from a year ago. The increase was attributable primarily to higher Permian volumes generating higher margin across our G&P and L&T segments and contribution from 100% ownership of our Badlands assets. Adjusted EBITDA was roughly flat for the first quarter. Record Permian and NGL transportation volumes were offset by lower marketing margin, sequentially weaker commodity prices and the impact of our planned turnaround at our fractionation complex in Mont Belvieu. 2025 is progressing on track with a strong first half and our continued expectation of increasing Permian volumes for the remainder of the year. We continue to estimate full year 2025 adjusted EBITDA to be in a range of $4.65 billion to $4.85 billion. In June, we successfully completed a $1.5 billion debt offering comprised of $750 million of 4.9% notes due 2030 and $750 million of 5.65% notes due 2036. We used the net proceeds from the debt issuance to reduce borrowings on our commercial paper program and in July to retire $705 million of 6.5% notes due 2027. In July, we also extended the maturity of our accounts receivable securitization facility to August 31, 2026. At the end of the second quarter, we had $3.5 billion of available liquidity and our pro forma consolidated leverage ratio was 3.6x, comfortably within our long-term leverage ratio target range of 3x to 4x. With projects tracking ahead of schedule, our announced full run extension in the Permian Delaware and spending on long lead items for additional Permian gas processing expansions, we now expect net growth capital spending for 2025 to be approximately $3 billion, and we continue to estimate 2025 net maintenance capital spending of $250 million. With the recently enacted tax legislation and its return of 100% bonus depreciation, we expect we will no longer be subject to the corporate alternative minimum tax, or CAMT in 2026 and will defer becoming a material cash taxpayer beyond 2027. As we continue to assess the benefit to Targa, we could see the deferral of cash taxes further out depending on a variety of factors in the out years. Shifting to capital allocation. Our focus is more of the same from Targa: maintain our strong investment-grade balance sheet, continue to invest in high-returning integrated projects and return an increasing amount of capital to our shareholders. During the second quarter, we repurchased $324 million in common shares at an average price of $165.86 per share. Continuing our track record of executing opportunistic share repurchases as part of our all-of-the-above capital allocation strategy. This week, our Board of Directors also authorized a new $1 billion common share repurchase program. This brings total available share repurchase capacity to approximately $1.6 billion as of June 30, 2025. This authorization adds to our flexibility and is purely a continuation of our existing program. To remain steadfast in our strategy of continuing to target returning 40% to 50% of adjusted cash flow from operations to equity holders over time through a growing combination of dividends and opportunistic share repurchases. We are in excellent financial shape with a strong and flexible balance sheet, and we are well positioned to continue to create value for our shareholders.

Thanks, Will. For Q&A, we ask that you limit to 1 question and 1 follow-up and reenter the queue if you have additional questions. Operator?

Our first question comes from the line of Spiro Dounis from Citi.

First question, Matt, wanted to go back to your comments in the prepared remarks just around your ability to historically outperform the basin. The tone of this call is seemingly starkly different than a lot of your peers this season, and so I just want to get maybe your latest thoughts on your ability to keep outperforming here, why you think you've been able to consistently do that. And if you're willing to maybe put a number on what you think that outperformance might look like going forward?

We have really seen over the years, the volumes on our Permian system continue to grow. It feels like we have not only the largest footprint, but a footprint that's really over some of the best rock in both the Midland and the Delaware Basin. So I think it's a combination of having the largest footprint where we can offer redundancy and reliability to our customers, which is highly attractive to them. And just being over some of the best rock in the area. So I think it's a combination of all those things. And I would say, our producer set are some of the largest, most active producers that haven't really varied their drilling plans as maybe much as some others have. So I think it's a combination of all of those things; it just gives us continued confidence not only in the back half of this year but as we look out in '26 and beyond, the same factors that have allowed us to outperform the basin over the last several years. Those attributes are still in place as we look forward.

Great. That's great to hear. Second question is just maybe moving to NGL margins. It's another common theme this quarter that seems to be focused again. I think there's a lot of concern about overbuild. Maybe narrow export arbs and so there seems to be kind of a pointing down of the margin environment going forward. Just curious if you could just update us maybe over the medium term, how you see the outlook? And if there's any risk to margins skew from here?

This is Scott. Regarding the export aspect of our business, I want to highlight that we have an increasing supply coming from our gas processing operations, supported by long-term customers and strong producers associated with our facilities. Consequently, we have significantly enhanced our midstream infrastructure, including expanded pipelines and fractionation capabilities. Additionally, we are undertaking expansions at our export dock this fourth quarter, and we have a larger project scheduled for the third quarter of 2027. We all recognize that there is a rising global demand for LPGs for petrochemicals, PDHs, and various domestic and industrial needs worldwide, which suggests that the market will continue to grow. Our dock has consistently been highly contracted, which means we have not relied heavily on the spot market. While discussions about the market maturing are common, we have maintained long-term contracts that have been in place for several years, and we don't foresee any changes in that aspect. Currently, there are four exporters along the Texas Gulf Coast, three of which provide products to Mont Belvieu, and one operates further south. When considering future expansions or new market entries, I do not anticipate significant shifts in competitive dynamics because they have already established themselves. Ultimately, it comes down to who holds the source of supply, and I have strong confidence in Targa's position in this regard. Once again, I emphasize our gas processing footprint, the long-term contracts we maintain, and the infrastructure we have developed to facilitate transportation across our docks.

Our next question or comment comes from the line of Keith Stanley from Wolfe Research.

Curious how you're thinking about competition in the Northern Delaware. You were kind of a first mover through Lucid and gas treating and AGI wells, but it seems like it's becoming a bigger and bigger focus for a lot of your peers.

Yes, I don't disagree. Obviously, you've seen enterprise and now MPLX come in and buy treating companies to address the sour gas situation in the Delaware Basin. As we've said before, obviously, we're the largest treater of sour gas in the Delaware Basin. We have the best capability. We have 2.3 Bcf a day of treating capacity. AGI wells with eyes on expanding that as our sour gas volumes grow. Frankly, Targa has been treating our gas almost since its inception, right, with 1 of the first acquisitions that was done as Targa. And certainly, a lot of our employees have been dealing with our gas for years. It is a core competency. And I think when we started looking at the Delaware Basin back in the 2016, '17, '18 timeframe, we pretty quickly recognized that there were economic benches that had sour gas production that producers were reluctant to develop because there weren't solutions to handle that gas. So I would say as much as 8 or 9 years ago, we put a strategy in place; one, we bought out rigor right, and they had some sour gas infrastructure. We leveraged off of that as we looked at Lucid; that was part of the overall equation. I mean it's really a recognition of how much sour gas capability over the long term is out there. And what I would say is that the competition is fine. We compete on all basis in the midstream business, obviously. We've got a ton of acreage under contract that continues to get developed. We continue to add, as we said, in our commercial success, acreage that covers sour gas production and as the Avalon, Bone Spring gets developed in the future, we're very, very well positioned. And certainly, the Wolfcamp in certain regions of the basin that we have under contract also has CO2 or H2S or the other or both, and Targa is very, very well positioned to handle additional growth. Like I said, we've got a ton of it under contract already.

Yes. And just to add to that, we've been competing in that business for years. And one of the things that gives us, I would say, competitive advantage is our Red Hills complex over a Bcf a day can handle sour, it's connected to our Bull Moose Wildcat complex, which can also handle sour. So we have the scale and redundancy to offer better run times for our customers. And it's running sour; there are more operational issues you're going to have than running sweet. And so we offer, I think, a unique set of services to our customers.

Thanks for that detailed response. For my second question, your business continues to show strong growth. As you have accelerated some capital expenditures into 2025, should we expect the 2026 capital expenditures to decrease year-over-year, or might that not be the case considering the growth you're experiencing? Additionally, it appears that NGL pipeline capacity is being filled quite rapidly.

Keith, this is Jen. I'd say that from where we sit today, the assets that we have in progress right now, we expect them to come online and be highly utilized; hats off to our engineering and operations teams for figuring out if there are certain projects that they could get on a week, a month or, in some cases, a quarter sooner because, again, they will be very much needed. Look, it's August right now. I think that from our perspective, it doesn't make sense to front-run producer budgeting cycles this fall. We'll get a lot more information from producers around 2026 that will inform our 2026 capital budget that will come out in February. But certainly, we believe that where we are spending capital is very much along our core competencies, very much consistent with the rates of return and track record that we've been able to demonstrate previously. And I think you're trying to see us continue to be capital efficient where it makes sense such that when projects come online, there are volumes essentially available to base load them such that the returns are better than we made an investment decision. So I think all of that means that we'll continue to work through our growth capital plan for 2026. We believe there's a lot of growth on our system, and we believe that we can execute on that growth and continue to generate attractive returns, which at the end of the day, is what will create shareholder value.

Our next question or comment comes from the line of Jeremy Tonet from JPMorgan Securities.

Matt, I think you talked about going into the end of the year into '25 headed into '26, potentially even in a stronger position. Just wondering if you could share more data points you're seeing that provide the confidence there?

Yes, sure. We really saw, I'd say, volumes for the first half of this year. We're more or less kind of in line with our expectations at the beginning of the year. Maybe the first quarter was a little bit softer with some operational issues. And what we really saw, I'd say, later in the second quarter, we really saw volumes start to ramp. And then I gave the color on the call; we've seen in July volumes up another processing plant worth of gas just in the month of July relative to the second quarter. I didn't give a number; August is up a fair amount from even the July numbers. So that's giving us confidence that the well connects that we have on our schedule, the volumes coming on are starting to really flow through our system. And then with Pembrook II coming on, that should provide some relief as well. Midland is pretty much full right now. So we really need that Pembrook 2 plant to come on, and that should give us further volumes over the back half of the year. So we're only just in early August, but we would expect that for the momentum we have kind of early in the first part of the second half of this year, if that continues, it just puts us in a really strong position as we exit. And that's what we're trying to articulate.

Our next question or comment comes from the line of Jackie Koletas from Goldman Sachs.

I was wondering if you could just provide a little bit more detail on the associated expectations or potential returns on the Bull Run extension and what the commercial structure, if any, looks like there?

Jack, this is Jen. I'd say that from our perspective, Bull Run and the extension is just a natural extension of capabilities that we are already very good at in terms of putting pipe in the ground and moving molecules and trying to provide our producers with better solutions. So from our perspective, this extension is taking essentially gas from our Bull Moose and Wildcat complex up in the Delaware, bringing volumes down to Waha on a 42-inch pipeline. So it's really supported by the volumes that we already have flowing in our existing assets there and then the expected growth that we would expect from the Delaware going forward. So not that dissimilar to other parts of our business, where we're able to aggregate volumes on the gathering and processing side and then enhance our capabilities for our producers to provide better redundancy, better outlets to our producers by essentially enhancing our capabilities as we move through time. So this is just a natural extension of that.

Got it. That makes sense. And then just second, buybacks in the quarter were fairly strong when you authorize a new repurchase program as well. How do you anticipate to balance future buybacks with other uses of capital over time? And just talking about the cadence of potential buybacks going forward?

This is Jen again. I think we very consistently try to demonstrate that our share repurchase program is opportunistic, and that is the standard that our Board of Directors holds us to as we allocate capital to that repurchase program. You clearly saw us to be very active in the second quarter. We thought that there was an opportunity where global macro concerns were disconnecting a little bit from what we perceive to be the fundamentals of the Targa business and the intrinsic value of Targa. And as we look at our short, medium and long-term outlooks, really weren't seeing anything change that was reflected by some of the downward activity that we were seeing in our share price, and that's why you saw this step in. I think we'll continue to be the all-of-the-above approach that we've demonstrated so far, which means that your ability to predict our activity quarter-by-quarter is going to continue to be very difficult. We're continuing to allocate capital to very attractive organic growth capital projects, but we have a very strong balance sheet and that provides us with a lot of flexibility as well to continue to execute in returning more capital to our shareholders. So it just puts us in a really good position to be able to pull different levers as we believe we see the opportunities present themselves.

Our next question or comment comes from the line of Manav Gupta from UBS.

I just wanted to go back. Earlier in the year, you did take 100% ownership of Badlands. I just wanted to understand, has that transaction met your expectations and your goals and have those assets been performing in line with your expectations? And how does only 100% change your view of the asset versus not owning the same percentage as it did before? So if you could talk about that?

Yes, sure. Yes. So the Badlands transaction that we announced earlier this year was really taking out Blackstone, which we really view, they had a preferred interest that it was refinancing their preferred interest and had some cash flow savings because we could just put it on our balance sheet. So it's been performing, yes, as expected. Overall, volumes up there have continued to be relatively flat. There are some signs that production could be increasing here over the next 1 to 2 years or so, but it's been relatively flat, and it's been performing, I'd say, in line with our expectations. I'd say with the enhanced competition, as you look out going forward for NGLs, I'd say, yes, those assets do pose more strategic value and there's some more opportunities there to do something on the NGL side of the business. And so we're just evaluating all those opportunities, and we'll think thoughtfully about what makes the best sense for Targa.

Perfect. And you obviously have a very strong line of organic growth projects, but we are also seeing multiple transactions getting executed in the Permian. I think 2 were announced last 1 day or so. And in terms of you have the balance sheet, trying to understand what could be a good criteria for any bolt-on M&A that you could undertake just to further increase your presence and that could add to your existing footprint?

Yes. And we continue to look at acquisitions. We haven't had anything of really significant size and kind of the asset market for a while, kind of going back to Lucid in 2022. But we continue to look. I'd say we have a really strong footprint on the G&P side of the business. We have a really strong NGL presence. So we have all the strategic needs of our core business met. And so now what we're really looking for, are there nice bolt-ons that could supplement our base strategy. So our focus has been on organic growth. We have a lot of growth opportunities just executing the number of plants that we have and our downstream business. So that continues to be our focus. But if there's something that bolts on really nicely to our G&P footprint, we'll continue to look at it. As I said before, the bar continues to be high for us because we have all the strategic needs met. But if there's some nice synergies or opportunities, we'll continue to be thoughtful and look at those.

Our next question or comment comes from the line of Michael Blum from Wells Fargo.

I wanted to ask about the LPG export DAC. You indicated it was effectively full for the quarter, but I noticed that volumes were down sequentially over the last two quarters, suggesting you are operating below your total existing capacity. Could you clarify that, especially given your high level of contracts? Also, I appreciate your strong competitive position, but there are new entrants entering the market. How do you plan to address the increasing competition from the Permian pipeline all the way to the export dock?

Michael, this is Scott again. I'll start on the export side and then perhaps given the fact that we've got Ben here with us today, and who he's been working the transportation fractionation side of our business, he can talk a little bit about NGL pipes out of the basin as well. But I'd really refer back to my earlier comments and that is our strategy around the export dock really starts with our availability of supply that is originating from our gas processing plants. Again, long-term contracts that will feed into our overall system whether it be pipe, frac, et cetera, all the way down to our export dock. Again, adding another potential entrant or participant in the export business along the Texas Gulf Coast really does not change our overall strategy. We will be competitive. But I think, again, given the fact that we have been highly contracted for term business, and business, quite frankly, with a lot of those contracts has volumes that ramp up over time that will complement our expansion on the back half of this year and then the expansion we've got in the third quarter of 2027 at those what I would call mature rates. I feel very comfortable with our overall position as it relates to that. When we look out there, the market again has been competitive for a while, and we've done very, very well in that sector. on the export side of our business. And we, again, I think it goes back to the availability of supply that will stay on our system and move across our overall docks and feeding a growing global demand. And then I'll turn it over to Ben just to talk a little bit about NGL pipes out of the basin.

Thanks, Scott. I believe you expressed it well regarding our entire downstream footprint. We are indeed expanding based on millions of dedicated acres across various basins. We have a clear view of future volumes. Additionally, we continue to achieve commercial success as our customers appreciate the strong offerings we provide through our integrated system and extensive footprint, which includes significant redundancy. This is the foundation of our approach to all the expansions in the downstream sector.

Our next question or comment comes from the line of Jean Ann Salisbury from Bank of America.

The Permian gas egress has been tight year-to-date, which you can see in the depressed Waha pricing. But there's a lot of pipeline capacity coming on next year that most people including us think will unlock the basin for the rest of the decade. Is that how you see it as well? And when those pipelines come on next year, would you expect to see a sustained move for you off your fee floors?

This is Bobby. We're really excited about the recent announcements regarding egress pipes. They represent a significant opportunity for us because they allow gas to flow to the hub, giving our producers options for direction and pipeline choice, rather than being restricted to just one or two pipelines near our plant. As we consider egress in relation to the basin, we are eager for these developments. Our strategy remains the same: we want to ensure egress happens, whether that means putting gas on existing pipes, building new ones, or participating in pipeline projects. With the current pace of developments, we anticipate having ample egress supply when all these new pipelines come online. Regarding fee floors, I'm not going to speculate on price movements, but increased Waha pricing would be beneficial for those fee floors. I'd like us to consistently be above those three floor levels since we've generally been below them recently, and achieving that would provide a positive boost to our business.

Great. And now that Grand Prix is filling up, can you talk about the pros and cons of using more third-party NGL transport from here? I mean I guess the pro is like obviously you don't have to spend a lot of CapEx. But should we expect a 0 or $2 per gallon of extra cost on your incremental downstream volumes from here if you're using third-party transport?

This is Jen. I'll start and then I'll throw it to Ben. I think that from our perspective, what utilizing third-party transport allows us to do is one, provide a little bit of diversification in just ensuring that not all of our volumes are flowing on our pipe. But two, it's really to be capital efficient. And I think that's an indication really of how well we're all working across the space. I think that an overbuild situation doesn't really benefit anybody. So you're seeing us work very well with our peers to figure out how to continue to move our molecules and a lot of the growth that we have, but do it in a manner that's efficient across the space. I think that the way that we evaluate it is, one, just making sure that volumes will continue to move. We're adding a lot of processing plants and a lot of incremental processing plants are going to drive a lot of additional NGL volumes into our system and ensuring that we are continuing to provide our customers with the best possible service is what is paramount to us. So that's really evaluating what are the alternatives out there, what are those alternatives cost. And therefore, with all of that put together, what makes the most sense for Targa over both the short, medium and really the long term. Ben?

I think that is all right, Jen. I'd just remind everyone, we have multiple flexible medium-term offloads that as our volumes are growing, we can move into those and time any future expansion in the most optimized way for bringing it online and for the capital spend. And then when that expansion comes online, we'll have volumes to put out at driving good returns.

Our next question comment comes from the line of Sunil Sibal from Seaport Global.

First of all, congratulations to Scott on his retirement and also to Ben, on his new role. So it seems like from your comments that you probably are getting ready for the next set of processing capacity additions. I was curious how should we think about capital costs for those processing brands? Are you seeing any meaningful change considering the inflation of the environment, especially on the material side? And how does it impact any of your returns?

Sunil, this is Jen. First of all, I'd say that our engineering team does a phenomenal job of assessing all of the options really available to us both in terms of utilizing the Targa standard plant design and then figuring out whether a system is sweet or sour, what additional information we'll need and then identifying the right third parties for us to work with that can really keep our costs as low as possible. So definitely, a big congratulations to our engineering team for the success on the plants that they are bringing online, the plants in progress. And then, of course, they're already thinking about the plants in the future. I think you're right that from our perspective, costs have risen, but we've also done a really good job of managing those rising costs. You're seeing us co-locate plants, so instead of just having one plant at a site, you're seeing a lot of sort of vintage two plants at sites like the Bull Moose 2 plant, Pembrook 2 plants. That allows us to benefit from some of the shared services across facilities, which helps us manage our costs. And again, I think that's part of the benefit of having such a large and flexible system in place like we have. But we have seen costs rise. So depending on whether a plant is sweet or sour, costs are probably averaging more between, call it, $225 million to $275 million. But again, our team is doing a really good job of managing plant design, supply chain, making sure that we are ahead of any potential constraints and issues that could create rising costs to just make sure that we are continuing to build best-in-class facilities at best-in-class costs.

Our next question comment comes from the line of Jason Gabelman from Cowen.

I wanted to ask again about the trend in fixed fees in the Permian Basin. It seems there are various factors at play, including a full system in the Midland Basin, along with rising costs and increased competition in the Delaware AGI. Considering all of this, what is the outlook for the fees you can secure from customers? Are they increasing, decreasing, or remaining stable? Any insights would be appreciated.

Yes, sure, Jason. I'll start and Jen or Pat want to jump in. As Pat mentioned earlier, we've faced competition all along. It's changed. It used to be you go back years, there was a lot of private equity coming into the space and there was a lot of competition on the G&P side. We've been competing with the recent acquisitions; go back over the years, we were competing with the predecessor and now we're competing with the acquirer. So there's been a lot of competition on G&P. Our base business, we have long-term contracts. Typically, GMP contracts are 10 years; we have a lot of 15-year contracts. So we have long-term contract protection. And we have multiple plants, reliability, redundancy, the largest system, which affords us a really good opportunity to compete with others as they're comparing the Targa offering versus the next best competition. So there's always been competition. I think we compete pretty well all the way from GMP and all the way through downstream.

This is Jen. I'd just add that I think from our perspective, we've got the best commercial team in the business, which means that we are creative and entrepreneurial and willing to work with our customers. And so to the extent that there's an opportunity, for example, to think more about the longer-term game than the shorter-term game, if there's a chance to go and acquire more acreage, but it means that we blend down into a lower fee, we'll, of course, play whatever gain best supports our producers and creates the most value over the long term for our shareholders as well. So I think we just do a really good job of working well with our producers and broader customers to figure out what are their needs, how are those needs changing and evolving? And then how can we best structure our contracts to meet those needs.

Yes, that's great. And my follow-up is just on the EBITDA guide. And the $200 million range is unchanged, but there's only a few months left in the year here. So wondering as you look at the balance of the year, the risks to coming in at the high end or the low end of that range.

I'd say that it still feels like there's a lot of the year left to go. It feels more like we're halfway through the year here with a bunch left to go. But I think from our perspective, as Matt's comments indicated, we feel really, really good about where we are for 2025. A big part of what we came out in February and said was that our guide and the range was really predicated on us continuing to see volume growth, particularly in the back half on the G&P systems and bringing that incremental volumes through the rest of our integrated system. And clearly, with all the data points that we've provided today, volumes are materializing. And I think we've got a lot of conviction based on where we know producers are with well completions and continued activity back half of this year. Starting to feel really good about the volume outlook for Targa, not only back half of this year, but then the implications for 2026. I think there are some potential tailwinds that ultimately, we'll have to see how those present rest of the year, related to commodity prices. We saw weaker commodity prices in the second quarter. We've seen lower gas prices on the Waha side thus far here in the third quarter. So commodity prices, we don't have a ton of exposure, but in the first quarter, we benefited from about $10 million of margin above fee for levels. In the second quarter, we really had no margin above fee floor levels. So to the extent we get any tailwinds there, certainly, that would be additive in the back half of this year. And then we also don't tend to forecast our marketing business on both the natural gas and the NGL side. So to the extent we see some tailwinds there, that would be additive back half of the year as well, and fourth quarter is where we typically see more strength in marketing opportunities than the second and third quarter.

I show no additional questions in the queue at this time. I'd like to turn the conference back over to management for any closing remarks.

Thanks to everyone for joining the call this morning, and we appreciate your interest in Targa Resources.

Ladies and gentlemen, thank you for participating in today's conference. This concludes the program. You may now disconnect. Everyone, have a wonderful day.