Hello, everyone. Thank you for joining us and welcome to the Kinetics second quarter 2026 results. After today's prepared remarks, we will host a question and answer session. If you would like to ask a question, please press star one to raise your hand. To withdraw your question, press star one again. I will now hand the conference over to Alex Durkee, head of investor relations.

Please go ahead. good morning and welcome to kinetics second quarter 2026 earnings conference call our speakers today are jamie welch president and chief executive officer and trevor howard senior vice president and chief financial officer as a reminder today's discussion will include forward-looking statements please refer to our sec filings for a discussion of the risks that could cause actual results to differ materially we will also reference certain non-GAAP financial measures, reconciliations can be found in our earnings materials and on our website. With that, I will turn the call over to Jamie.

Thank you, Alex. Good morning, everyone. Kinetic delivered the strongest financial results in our history. Our performance was driven by exceptional operational execution, strong system performance, and a supportive commodity price environment. I'm proud of our team, whose focus, discipline, and commitment to excellence continue to drive these results accordingly we are updating our full year 2026 adjusted EBITDA guidance upwards by 17 million dollars at the midpoint or 7% reflecting the strong first-half performance and confidence in the outlook for the remainder of the year Trevor will discuss the key drivers behind our guidance update in more detail shortly. The confidence embedded in our revised outlook is reinforced by what we're seeing across our footprint today. Customer development activity continues to build. Commercial momentum is the strongest it has been since our inception in 2022, and our team is executing at a very high level. Combined with improved market conditions, these trends position us well for a strong finish to 2026 and tremendous follow-through into 2027. We are seeing broad-based momentum across our integrated gathering, processing, and downstream platform. Conditions across the Permian continue to improve as Waha pricing has recovered from the extreme dislocations experienced for the first five-plus months of this year, driving a step change in producer curtailments since mid-June. At the same time, the more constructive crude oil environment continues to support attractive development economics, and we're seeing a continuation of customer activity pull forward across our footprint, with some of that benefit to materialize in the second half of 2026. Reflecting these trends, Permian recount has increased 8% since February, with over 60% of that growth coming from the Delaware Basin. Against this backdrop of accelerating activity and growing producer demand, we continue to proactively position our system for the next phase of development. In May, we reached FID on King's Landing 2. The message from customers has been crystal clear. Incremental sour gas treating and processing capacity is needed to support their development plans. As such, we elected to increase the processing capacity of KL2 by 50% to 300 million cubic feet per day. Since announcing the expansion, we have already purchased cryoprocessing, amine, and residue compression equipment, and the project is now expected to be completed in mid-2028, earlier than previously communicated. Upon completion, Delaware North sour gas processing capacity will exceed 700 million cubic feet per day and Kinetics' total system-wide gas processing capacity will surpass 2.7 billion cubic feet per day. Importantly, we're already looking beyond KL2. This week, Kinetics Board authorized procurement of long-lead equipment for the next stage of processing capacity expansion, proactively aligning our supply chain with accelerating customer demand. This positions us to manage equipment lead times, preserve development flexibility, and efficiently support the next phase of growth on our system. We have also sanctioned the commencement of work on expanding the capacity of ECCC. Our willingness to materially reinvest in our business reflects not only the visibility we have into customer development plans, but also our conviction in the long-term growth outlook for the Permian Basin. To that end, the market continues to recognize the Permian's critical role in meeting future U.S. natural gas demand growth. With LNG exports, power generation and data center development driving incremental consumption, the question has increasingly become where the gas will come from and how it will reach end markets. The Permian remains uniquely positioned to answer that call with more than 11 billion cubic feet per day of new basin egress capacity that has been sanctioned through 2029. Against this backdrop, Kinetics' integrated business is becoming increasingly valuable to customers, seeking both reliable flow assurance and premium-priced market access. During the quarter, we executed several commercial agreements that further strengthen the value proposition of our Permian to Gulf Coast platform, while expanding market access and optionality for both existing and future customers. First, we secured incremental firm residue gas access to Gulf Coast markets beginning in 2027, providing customers with enhanced flow insurance and premium netback pricing. We also signed new residue gas and NGL transportation agreements, supporting our Delaware North processing complexes, increasing operational flexibility, and securing critical downstream capacity as activity and volumes continue to grow across our New Mexico business. These agreements are excellent examples of our broader strategy to reduce our customers' exposure to in-basin pricing volatility by expanding access to premium end markets. More importantly, they reflect our differentiated approach to commercializing the value of Kinetic's integrated platform. Rather than competing solely on GMP services, we continue to leverage our downstream assets and market connectivity to deliver a comprehensive solution for producer customers. operationally our team executed very well during the quarter a significant driver of our record results was sustained system-wide performance reflecting both the strength of our operations and our continued focus on optimization opportunities across the system the eccc pipeline has been placed into service officially establishing that north to south connection across the western portion of our system between Eddie and Culberson counties. Rich gas volumes on the pipeline are expected to increase throughout the balance of the year as King's Landing reaches full utilization. At King's Landing, the acid gas injection and sour conversion project continues to advance with drilling operations well underway and phase one remains on schedule for in-service by year-end. In Delaware South, Diamond Vault, our 40-megawatt-behind-the-meter power generation project at Diamond Cryo, continues construction progress within service anticipated in the second quarter of 2027. Now, before I hand the call over to Trevor, I want to underscore how confident we are in Kinetic's position and long-term trajectory. The strategic investments we have made across our platform are delivering exactly as intended, strengthening our financial performance, expanding our commercial opportunity set, and enhancing the value we provide to customers. We're seeing the benefits of our integrated model come through in a meaningful way. Our assets are performing well, our team is executing with discipline, and the momentum across the business continues to accelerate. As customer activity builds and the need for reliable connected infrastructure becomes even more critical, Kinetic is uniquely positioned to deliver. We exit the second quarter with stronger earnings power, greater visibility, and a clear line of sight to continued value creation in 2027 and beyond. And with that, I will turn the call over to Trevor.

As Jamie highlighted, the second quarter was a record one for Kinetic. We reported adjusted EBITDA of $281 million, distributable cash flow of $195 million, and free cash flow of $105 million, reflecting strong execution across the business. Within midstream logistics, adjusted EBITDA increased 35% year-over-year to $205 million. Processed natural gas volumes were 1.74 billion cubic feet per day, flat year-over-year, despite an estimated 250 million cubic feet per day of Waha price-related curtailments. Results benefited from strong system operating performance, improved NGL recoveries, and condensate yields, optimization opportunities, and lastly, favorable commodity prices and spreads. Our pipeline transportation segment generated adjusted EBITDA of $83 million down year-over-year, primarily due to the divestiture of our equity interest in Epic Crude. This was partially offset by year-over-year outperformance at Permian Highway Pipeline, supported by lower fuel costs and higher gross margin, and better-than-expected throughput volumes at Chinook. At quarter-end, leverage was 3.8 times and liquidity exceeded $1 billion, and we expect leverage to decline further by year-end, even with our elevated capital program. Importantly, we continue to operate comfortably within our targeted leverage range of 3.5 to 4 times while maintaining substantial flexibility to fund attractive growth projects and return capital to shareholders. Turning to guidance, we are substantially increasing our full-year 2026 adjusted EBITDA outlook to a range of $1.04 billion to $1.1 billion. At the midpoint, the revised outlook represents a 7% increase relative to our original guidance issued in February and approximately 15% growth year-over-year on a pro forma basis for the EpicRude divestiture. There are four primary drivers supporting our revised outlook. First, our volume expectations have improved meaningfully since our May outlook. At the time, we expected low- to mid-single-digit volume growth due to the elevated Waha price-related curtailments. Since then, Waha pricing has normalized, curtailed volumes have returned to production more quickly than anticipated, and customer activity has continued to accelerate. As a result, we now expect mid-to-high single-digit volume growth year-over-year. Average curtailments are expected to decline to approximately 25 million cubic feet per day for the balance of 2026. And we expect to exit the year approaching 2.2 billion cubic feet per day of processed gas volumes with no curtailments assumed in the fourth quarter. Second, commodity prices remain favorable to our outlook. Updated guidance assumes forward market pricing as of July 28th and reflects a nearly 30% increase in WTI pricing and a nearly 20% increase in liquids pricing relative to commodity assumptions used in our original guidance in February. While Waha natural gas pricing remains well below our original assumptions, that impact has been offset by the significant Gulf Coast marketing gains realized in the first half However, as Waha pricing has improved and basis differentials have tightened, we expect those marketing benefits to moderate in the second half of the year and be replaced by the return of curtailed volumes. We remain substantially hedged through the year end at the top end of our targeted range of 40 to 80 percent, opportunistically adding incremental hedge protection in the second quarter and aligning with our rolling 12-month and 24-month targets. Third, operational execution across the system continues to exceed our expectations. Strong plant and compression run times, higher NGL recoveries, increased condensate yields, and continued optimization efforts across our footprint are expected to provide ongoing benefit through the balance of the year. And lastly, our pipeline transportation segment continues to outperform our original forecast, supported by stronger basin activity, higher throughput volumes, and healthy margins across our pipeline businesses. As it relates to quarterly cadence, we expect adjusted EBITDA to be between $260 million to $270 million in the third quarter and $270 million and $280 million in the fourth quarter of this year, supported by increasing customer volumes across the system and ECCC utilization. We are also increasing our 2026 capital expenditures guidance, including maintenance capital, to approximately $560 million. The increase is primarily driven by several initiatives that we believe represent highly attractive investments for our shareholders. These include King's Landing 2, additional optimization projects across our footprint, the purchase of compression equipment to address elongating lead times and an increasingly stretched supply chain, the acceleration of certain growth capital investments supporting customer development plans in late 2026 and early 2027, and right-of-way procurement for an expansion of ECCC. We have also started procuring long lead equipment for our next cryo beyond King's Landing 2, which positions us to better manage supply chain risk and preserve timing flexibility for our continued expected processing expansion. Turning to capital allocation, our growth-oriented philosophy remains unchanged. We continue to prioritize investing in high return organic growth opportunities that strengthen our integrated platform and expand the earnings power of the business. The increase to our capital expenditures guidance reflects the quality of the opportunities in front of us today and our conviction and our long-term outlook. Simply put, we believe elevated reinvestment today builds the earnings base that funds growing returns tomorrow. Alongside this reinvestment, we remain committed to a growing and well-covered dividend. In late July, we paid our second quarter dividend of $0.81 per share with dividend coverage improving to approximately 1.5 times, up from 1.2 times for full year 2025. We expect coverage to continue to strengthen through the second half of the year and into 2027, supporting sustained dividend growth consistent with the framework we have publicly outlined. Operator, we can now open the line for questions.

We will now begin the question and answer session. Please limit yourself to one question and one follow-up. If you would like to ask a question, please press star one to raise your hand. To withdraw your question, press star one again. We ask that you pick up your handset when asking a question to allow for optimum sound quality. If you are muted locally, please remember to unmute your device. Please stand by while we compile the Q&A roster. Your first question is from the line of Spyro Dunas with Citi. Spyro, your line is open. Please go ahead.

Thanks, operator. Good morning, everybody. I want to start on the processing capacity first. Just looking at that 2.2 BCF a day exit rate, it seems like you'll be knocking on a door of capacity and maybe even exceed it in 2027. Jamie, I think you referred to the flow through there as tremendous. And so until KL2 comes online, it seems like you might have to look into some offloads. So curious, are we thinking about that dynamic right as we head into 27 and maybe just any plans to deal with those excess volumes here?

Yes, Spiro. First off, good morning. I think it is certainly something that we look at and analyze on a weekly basis with the ops engineering team, particularly with Matt Wall. We've got some projects underway where we're looking to rebuild center blocks of existing 200-a-day accrues to continue to increase and upsize capacity. I think there's more to come on those particular topics. So the idea comes in a couple of different flavors. One is what's the most you can get out of the existing footprint and system capacity today? What could we do to improve it? Two, what offloads on an interim basis could we start to consider as we get further and further into 2026 and into 2027 that would basically bridge us. So both dynamics are in play and both dynamics are being analyzed. We are obviously quite excited that KL2 looks like it's going to be earlier than what we have previously communicated. That's a good thing. I don't, you shouldn't, I mean, when we're looking to shave time we're looking at months and weeks we're not looking at you know moving it you know many months or a year or anything like that and obviously uh to that vein we decided that look given the on the supply chain side given what we're seeing it was important for us to get ahead of the next cryo and whether that's in new mexico or whether that's in texas and the location of that is TBD. We want to be ready and we want to make sure that we don't have any timing impediments to basically execute on that plan.

Got it. That's a helpful color. Second question here, maybe just focusing on the operational outperformance. You called it out in the materials and the remarks here, and it appears to actually be a sizable contributor of some of the beat and raise going forward. So maybe just talk about what's suddenly driving this outperformance? Was this a specific initiative you guys have undertaken? Perhaps, if possible, maybe put some numbers on it for us. And as we think about the go forward here, is this something you expect to build on, or have we kind of seen most of it already?

I think, Spiro, I want to maybe just take you back. When we first bought Acquired Durango and talked about the acquisition, we identified that it was a system that needed remedial capital. It had a lot of, there was reliability issues, there were operational issues, there was, it was an aged system that needed a refresh. We have spent millions and millions on a concerted effort where we have replaced pipe, we have repaired pipe, we have repaired facilities, we have upgraded facilities, we have improved measurement, we have therefore improved reliability and run times. Our FLNU, if you know basically fuel lost and unaccounted for, reductions have been significant. Our recoveries have improvements have been significant. This was all part of the grand plan. It's taken us two years to get here, which is not surprising. We obviously had King's Landing in the interim, but it just took time. And now we look at the operational performance and we are seeing less of a marked dislocation between the operational recoveries and performance of the north versus what we have in the south. We have undertaken, you know, we do a lot of low-pressure gathering and processing, as you well know. We're probably one of the biggest, if not almost the biggest, on the low-pressure side in the Delaware Basin. So compressor stations and the usage of fuel at the compressor stations, whether that's lean gas, which was a big initiative that Trevor and Ross, together with Matt, initiated several years ago, where we converted our stations from rich to lean so we were not burning NGLs, was an initiative that we rolled out in New Mexico. And so we are doing things that, at the end of the day, continue to optimize our operational performance and improve, obviously, we see the overall system benefits, and you see them reflected in our financials.

It's great to hear, Jamie. I'll leave it there. Thanks, everyone.

Your next question comes from the line of Jeremy Tonnet with JPMorgan Securities, LLC. Jeremy, your line is open. Please go ahead.

Hi, good morning. Good morning, Jeremy. Just wanted to drill in a little bit more on these points, if we could. Just wondering if you could tell us where volumes are currently in that 2.2 that you see. Is that a 4Q average, or is that like a December 31st number? Just trying to get the trajectory, I guess, of volumes from today to year-end as that, you know, propels into 27.

Yeah, sure. Thanks, Jeremy. Trevor. If you go to page six, you can look at the far right bar chart. It is a 4Q 2026 average. Is that approximately 2.2 BCF a day? And then on the second part of your question, second quarter 2026, processed gas volumes was 1.74 BCF a day. We did disclose that there was approximately 250 million cubic feet a day of curtailments on average in the quarter. And then on a go-forward basis, we estimate that there's 25 million cubic feet a day of curtailments for the second half of the year on average so if you take 225 million cubic feet a day of return volumes that were previously shut in and that 2q 2026 number that puts you at around 1.95 1.96 bcf a day is how i would bridge that question got it thank you for that um and just you know coming back to system performance um you know great to see everything coming together there and just wondering i guess how do you think effective capacity for the plant stands right now versus kind of name play as we think about, you know, this volume growth, if it's going double digits into next year, just,

you know, how we think about that?

Look, Jeremy, it's Jamie. So I think as far as name play, you know, down south, most of our existing cryos are 200 a day cryos, particularly for East Toya, Pecos, and even Pecos Bend. We obviously did the expansion at Diamond, and so we get almost 720 million cubic feet a day out of those three cryos. So set another way, it's like 240 would be max that you could get. But you'd probably be sacrificing recoveries if you're sort of running it at that very top end. I think we are looking at additional residue recompression, center block rebuilds, which should be able to get you between close to 220, 230. I think it's probably somewhere within that frame. I think Matt is on. He can sort of jump in here for the 200-a-day cryos. And as you know, of those, we have five in the south. So if you can get 20 to 30, you're getting 100 to 150, or set another way at the top end, 75% of another 200-a-day cryo. Matt, you want to jump in there?

Yeah, no, I think all that's fair. In general, I'd say through residue compression upgrades and then expander center section changeouts, we can see an incremental end of 15% above nameplate on any of the cryos down south.

So that helps us, I think, Jeremy, in the context of what we're doing. And obviously, we've been spending, you know, we obviously are focusing also on the north of what we can get out of those plants. Dagger Draw, Maljamar, obviously King's Landing will be running. We expect it will be at around 220 with the additional residue recompression. So I think, you know, we are maxing out our processing capacity. And as I said earlier on, in response to Spiro's question, we're also analyzing the probable and potential need for offloads in the short term sometime in 27 in advance of having King's Landing 2 come on in 28.

And Jeremy, just to clear one thing up, the 2.4 BCF a day of processing capacity that we disclosed, that's effective processing capacity as of today.

Got it. Thank you for that. And one last quick one as it relates to produced water. I think it looks like it might be heading down a little bit. Just wondering, you know, what's happening with the water side. You know, it seems like water is increasing overall for the basin. Just wondering, is this a mixed shift in wells or anything else at play here?

I think at the end of the day, it's as simple as we've got some large new projects and timing is impacting it. So I think it's more of a temporary situation. But I think, you know, there are some fairly large developments on the water side, which will see volumes rise pretty materially.

Great. That's helpful. I'll leave it there. Thank you. Thank you.

Your next question is from the line of Teresa Chen with Barclays. Teresa, your line is open. Please go ahead.

Good morning. Thank you for taking my questions. Going back to the macro side of things, can you elaborate on your earlier comments on customer activity and tell us what you're observing in terms of producer behaviors at this point? Come measure it with your updated comments on curtailments and volumetric guidance, as well as touch on the accelerated spend related to supporting customer developments until late 2026 contributing to the higher capex guidance are there specific areas you're observing this more than others and as we exit 2026 any early thoughts on the two directional trajectory of customer activity for 2027. teresa thanks um let me see if i can uh break it down as far as uh let me deal with the the the macro we're six months into a conflict with iran we're still Well, you know, literally we live day by day in the context of whether there's resolution and sort of the return to more normal times or whether there's not.

We see, obviously, we see constructive overall commodity pricing. $75 is a very different place than $60 or something in the high 50s which obviously was a time that we had to endure during 2025 so we continue to see a lot of the smaller producers that have literally looked to capitalize and we said this in our first quarter remarks back in May that they have really accelerated activities And so they are smaller, maybe in size, but there are more of them, and particularly up both in the north and sort of areas in and around the south, we've seen that activity continue. As it relates to the pull forwards, there were a lot of fairly large developments which were on the schedule and on the turn in line plans from various producers that were pulled forward from mid-2027 or later in 2027 to early 2027 or in a couple of cases into late 2026. And so that activity is what obviously has created the need for additional well-connects. I go back to the point of so much of what we do, absent only a few customers, is all low pressure. So we are literally building to the CTB. And therefore, you know, for us, we're spending, you know, with some of these pads, you've got not just well-connects, but we have compressor stations. And we have other things and other ancillary equipment that we – ancillary infrastructure that needs to be built. So that's really the genesis and the reason for, obviously, some of the increase in the capital that we saw when we're moving up from the top end of our range, which we told you when we FID'd KL2 that we were at the top end at 510. We're now – we're saying approximately, you know, 560. So I think we see a lot of activity right now. And I think particularly in New Mexico, that is remaining very much supreme as far as just the amount of activity and how the depth of it.

And even in the south, we're seeing obviously with more constructive Waha and the ability for people to use Gulf Coast degress. we're seeing a lot you know increasing activity down south as well so we got the best of both worlds yeah i'd like to just emphasize jamie's last point there the capex pull forwards that you see in 2026 for development that is later this year and then first quarter second quarter of 2027 that we have to prepare for that's really large cap independent emps in delaware south we are seeing an acceleration of activity in new mexico as well but that incremental capital that you're seeing in 2026 really is the Delaware South system. And that's just part of the reason for that is just timing for new wells to be planned for and get connected to the system. In Texas, it's one to two quarters faster than what you see up in New Mexico. So we are planning in New Mexico right now for second half of 27. Prospects look very good. But as it relates to 2026 CapEx, really that's a Delaware South phenomenon.

Thank you. So that's very helpful. And then maybe on the cost side of things, can you update us and remind us where you are in terms of incremental savings related to your NGL recontracting activities? And also on the residue side of things, I believe you had entered into some short-term contracts back in November. Can you remind us when that rolls off and how that bridges into your recent capacity contracted beginning in 2027?

Okay. On the NGL side, I think we said in May and certainly in February, we have a pre-existing flexible solution as we see some of our Delaware South contracts, two of which roll off over the remaining passage of this year. It gives us a lot of flexibility. The rates are obviously market and quite attractive. Most recently, obviously, we've been tackling the Delaware North. We announced that we just signed a contract that gives us a lot of flexibility as it relates to our three complexes up there, Dagger Draw, Malchema, Kings Landing. Very attractive rate. We're very happy with flexibility it provides us going forward. So we feel like that's another the box that's checked on our list of, on our to-do list. As it relates to residue, the, what we contracted for last year doesn't roll off. That remains as it is and will going into the, into going forward. And obviously that sort of stages into, I think, into 2028 when And we've got, I think it's Iger, which comes on as the pipeline, and we have some capacity on that. As relates to the newest capacity additions, they are supplemental because, obviously, you can imagine, the first five and a half months of this year has been a crisis for anyone having to sell gas at Waha on such a negative basis. And therefore, everyone wanted to get out. and they still do. And I think honestly, while there's a reprieve right now, which we're very glad for, and we hope that that continues and we continue to see more egress capacity on the horizon, you know, I think what we're all potentially missing is the amount of gas that we continue to see building from all producers across the Permian Basin is just this rising tide that doesn't seem to abate and will not abate. And therefore, the prudent action for any producer is to have at least some or all of your residue pricing at Gulf Coast or a premium end market versus the whiplash that you get at Waha. So we've been supplementing our capacity stack, And we will continue to do so because we have a, I would say, we continue to see that need from our customers.

Thank you very much.

Your next question is from the line of Jackie Colitas with Goldman Sachs. Jackie, your line is open. Please go ahead.

Thank you so much for the time. I think you touched on a little bit, but just talking on guidance, you know, recently raised full year, reflecting a strong first-half performance. As we look into the second half of the year, you outlined a transition where, you know, moderating marketing gains will be offset by the return of curtailed volumes. How do you think about the incremental upside from here to expectations? You know, what could bring you maybe closer to the upper end of that new guidance range and where you may be most conservative here?

Jackie, it's Jamie. I'll start this, and Trevor's penciling out already his thoughts. But I think, look, there's so many facets to our business. There's a macro facet, and I give Trevor and Jared a lot of credit because they did really look to capitalize on some of the incremental commodity price outperformance across the balance of this year with their hedging over the course of the second quarter. But there's still a portion that moves. Obviously, Waha, are we going to stay at this level at sort of $1.90 or $2? Is it going to actually, is it going to return to the doldrums as we get into maintenance season come October or November, obviously when we have a lot of the existing egress pipes go through their scheduled maintenance periods. How do we think about overall outperformance in the context of our underlying producers and their forecasts and how we risk them? Like there are so many aspects that go into our business that I think, yeah, we try to navigate what we think is prudent and proper as we think about timing of pads, how a producer will bring a pad on, what the risking assumption versus their type curve that they will give us. So I don't know, Trevor, where you want to take this, but I think it's like we've given you the best available information that we have today. We are cognizant that we've obviously had a very solid first half, and we're very pleased with the results. And we want to continue to build on that as we go forward through the balance of this year.

Yeah, the other thing that I would add is, to Jamie's point, look, we receive customer development plans and customer volume forecasts, which we risk appropriately to the extent that our customers accelerate timing relative to our expectations and wells outperform, that is a source of outperformance that we've seen this year. I'd say another big one is the operational and system outperformance year to date so far. To the extent that that continues, that is a source of upside risk to the forecast.

That's very clear. I appreciate the color. And just As a follow-up, you touched a lot on the strong commercial progress and accelerated customer growth, leading to that incremental spending in 26. As you head into 27, how are you thinking about the run rate capital in the near term in order to meet that customer demand in comparison to your previous commentary of $200 million to $400 million run rate?

I think, Jackie, I've seen it from a lot of our peers, and I would very much echo the following sentiment, which is we are seeing a new, I would say, prudent paradigm on capital investment. And that really was the core of our revised capital allocation philosophy and that we saw the need, you know, literally we had to press the advantage. We had to make the investments. The overall investment returns was so compelling that we saw a need to continue. So what that means is, you know, this sort of level that we've got, 560, obviously, I think, for this year, you know, we've, I think, been very clear, you know, in that $500, $600 million range is, you know, very comfortable for us. And I think as we look forward, the nice thing about it is we can modify it as needed based on activity levels. You know, that's two cryos, right, in the context of how we think, you know, one cryo every 18 months kind of thing. That's how we sort of, I think, forecast it, at least on a longer-term basis right now, based on the plans and forecasts that we see.

I'll leave it there. Thank you so much.

Your next question comes from the line of Keith Stanley with Wolf Research. Keith, your line is now open. Please go ahead.

Hi, good morning. Wanted to start and follow up on the volume outlook. So if you take the Q2 volumes and add back the curtailments, you're pretty close to two VCF a day. So that's about 10% growth by the fourth quarter. Can you say where volumes are today on the system and just how much visibility and confidence you have on that ramp, which is pretty steep into your end?

Yeah, sure. Keith, I point you to one of my earlier responses, which is we had 1.74 BCF a day of processed gas volumes in the second quarter. If you normalize for the return of shut-ins of 250 million cubic feet a day, and then back out the 25 million cubic feet a day of shut-ins that we expect in the second half of the year, we're in and around 1.96 BCF a day as a kind of a bridge to where we are in the third quarter right now. As it relates to the second part of your question and getting from that 196 to approximately 2.2 BCF a day, we have a ton of visibility into that. We've been planning for several large packages in New Mexico for the better part of 12 to 18 months now that are starting to flow back, so we feel quite confident in being able to achieve that run rate in the fourth quarter of this year.

Great. Thanks. And then, Trevor, one of the follow-up on what you said earlier, that if the optimization and system performance improvement continues, that that would be an upside to your forecast and guidance. Is there any reason to think that you wouldn't continue to benefit from the performance improvements you've made in the system? Or is the uplift not as large if commodities are lower? Or just how you're thinking about that and how it's baked into the outlook at this point?

Yeah, that's a good question. I'll hit one of your last parts of the question, which is the unhedged portion, right? Obviously, because we have volumes that are exceeding expectations, those volumes that we've received in the first half of this year have been unhedged. So there is a margin component there. So I just wanted to hit that first. But as it relates to the, you know, $40 to $50 million of system performance in the full year of 2026, which is part of that green wedge that you see on page six, you know, a substantial portion of that has been realized year to date. There is a portion of that in the second half that we are forecasting, but not necessarily taking the outperformance that we've seen and then running with that on a go-forward basis. As it relates to the last part of your question in terms of where we could miss and why that would actually go away, I'll actually hand that off to Matt, our COO, so you can hit on that and what are some of the operational items as to why we want to experience the current run rate recoveries that we've been seeing thus far.

Yeah, probably an important thing to just talk on the ops performance is, specifically as it relates to Delaware North, is Jamie mentioned we did a lot of maintenance projects all the way across the system to improve recoveries, performance, et cetera. I think for the most part, we've gotten to a point where we're going to plateau, but I don't know that we'll see large gains from where we sit at today, but I don't expect us to go backwards. i mean i think that we'll continue to do what we've done to kind of get to the point where we're at on on system performance and hold it there but but for instance on recoveries for heavier components i mean we we've got to a point where i think is normal and i don't see us being able to go do projects to to get incremental recovery barrels on heavy components.

Hey, Matt. Hey, Matt. I was going to say, Matt, you and I talked about sort of more on the heavy ends. I think we've hit the optimization. We may still have some opportunities on the lighter end of the NGL barrel. But again, that's going to just take some more time and more focus and emphasis. It's a constant refinement of a recipe for a chef. That's probably the way to describe it. It's never going to be perfect at first. You're going to refine it, refine it to make it better. And I think that's what we're going to see, Keith, going forward. Good analogy. Thank you.

Your next question comes from the line of Julian Dumoulin-Smith with Jeffries. Julian, your line is open. Please go ahead.

G'day. This is actually Patrick Burford on the line for Julian today. Thanks for all your answers. There's been a lot of detail there that was very helpful. I just wanted to clarify maybe a little bit of the language. I think I've got in my notes here that your dividend policy was based around having that coverage ratio get back up to 1.6. And I think in your opening remarks, you said that you got to 1.5 and it could grow from there. Is there likely to be any change in your dividend policy from that, you know, in the context of your comments about your comfort with a $500 to $600 million CapEx program a year and the free cash flow you got going there?

Patrick, this is Jamie Welch. So the short answer is no. I mean, we're at 81 cents. We said we would grow it at 3% to 5% per year on a base case, and that once we got to 1.6% and above, we would start to see it grow in line with overall cash flow growth, which obviously would mean it's an outsized increase. So there's no risk whatsoever in the context of the base, nor a different approach at all relative to that, even with a – we, I think, assumed internally that the capital plan is sort of as we're seeing right now.

Yeah, the other thing that I would add to that is I think the bigger governor, for us at least in how we think about dividend growth, is probably leverage. And given the fact that – and as it relates to how CapEx influences that. But leverage, our leverage range is three and a half to four turns, our target's three and a half turns. Last quarter, we were at 3.8, so we're right in the middle of our stated range. Even with elevated capital budgets, I think in my prepared remarks, we talked about how leverage is expected to continue to decrease throughout the balance of this year. So very comfortable with where leverage sits, very comfortable with where dividend coverage sits, and no changes to our return of capital levers that we've outlined on page nine.

Great. Thank you. And then a second question was a little bit about further out along that CapEx timeline. I think it was Teresa's question, maybe. I think you talked about the ECCC will roughly double in size, and before you said it wouldn't take too much CapEx to expand that, and you've got your new cryos that you mentioned. Are we looking at a two-year program with that elevated CapEx program, or are you looking even further out keeping it that high?

Look, we're looking further out. I mean, like I had mentioned, New Mexico, for the pads that we're bringing on right now, we've been planning for 12 to 18 months. we're starting planning for, or we've already made significant headway on planning for the second half of 2027 program and then also starting into 2028. So we are really planning our business for 2028 and beyond. King's Landing 2 is expected to come online summer of 2028. We announced that we have initiated procurement of long lead items and equipment for the next cryo thereafter, which if you just take the timing between when we announced the FID of King's Landing and it's in service, it's around 24 months. So from here, we're already planning for additional processing capacity in the second half of 2028 or thereafter. So with that and Jamie's comments, in and around one cryo per year at $500 million to $600 million of total capital, growth capital is about four to five hundred million dollars per annum at those levels you know you add a cryo to that there's potential upside risk to that capex um but uh but to answer your question we're just we're looking at 27 we're looking at 2028 and we're already looking at 2029 and to the extent that you know the macro holds and producer customers continue to keep showing us these volume forecasts that require additional processing capacity you should expect capex to remain in and around these levels so long as we're building one cryo at a time perfect thanks very much for your

time. No problem.

Your next question comes from the line of Somya Jain with UBS. Somya, your line is open. Please go ahead. Just a reminder to unmute if you're muted, Somya. There are no further questions at this time. I will now turn the call back to Jamie Welch for closing remarks.

Thank you very much, everybody, for your time this morning. We wish you a great end of the summer. We'll be seeing you again on the circuit and with our next quarterly call in november this concludes today's call thank you for attending you may now disconnect