Good afternoon, ladies and gentlemen and welcome to the Targa Resources Corporation Third Quarter 2019 Earnings Webcast and Presentation Conference Call. At this time, all participants are in listen only mode. [Operator Instructions] I would now like to turn the conference over to your host, Mr. Sanjay Lad, Senior Director of investor relations. Sir, please go ahead.

Good morning, and welcome to the third quarter 2019 earnings call for Targa Resources Corp. The third quarter earnings release for Targa Resources Corp, along with the third quarter earnings supplement presentation are available on the Investor section of our website at targaresources.com. In addition, an updated investor presentation has also been posted to our website. A reminder that 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 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 Joe Bob Perkins, Chief Executive Officer; Matthew Meloy, President; and Jennifer Kneale, Chief Financial Officer. We'll also have the following senior management team members available for Q&A. Patrick McDonie, President Gathering and Processing; Scott Pryor, President Logistics and Marketing; and Bobby Muraro, Chief Commercial Officer. Joe Bob will begin today's call with a few strategic highlights, followed by Matt who will provide an update on business outlook. And then Jim will discuss third quarter results before we take your questions. With that, I'll now turn the call over to Joe Bob.

Thanks, Sanjay. Good morning, and thank you to everybody on the call. Before we get into our remarks, I'd like to acknowledge the recent retirement of Jeff McParland. Consistent with our long term succession planning. Most recently, Jeff served as President of administration. Jeff was also Targa's first CFO. On behalf of the entire Targa team, we thank Jeff for his tremendous leadership and help shaping our financial organization in Targa's early years. It continues to be an exciting time at Targa. We're beginning to benefit from numerous major projects now online, most of which began over 2 years ago. This year, we completed and commenced operations on approximately $4 billion worth of projects. Projects which have successfully transformed Targa into a leading integrated midstream company. These completed projects and the cash flow from these projects positions Targa very well. Our balance sheet and cash flow profile are expected to strengthen meaningfully as we move forward. And we will capture improved returns on capital, benefiting from our integrated platform and lower capital spin. I want to express my personal thanks to the exceptional team at Targa for their continued focus and commitment, executing on these projects, on our company's long term strategic priorities and most importantly, safely operating our infrastructure facilities every day. With premier assets and a premier reputation in both our gathering and processing business and in our downstream NGL business and with those assets and reputation complemented by our talented leadership and employees, Targa is very well positioned for the future. With that, I'll now turn the call over to Matt to discuss our business outlook.

Thanks, Joe Bob, and good morning. It certainly is an exciting time at Targa. Q3 was a strong quarter as we are beginning to benefit from the cash flow ramp associated with our significant investment cycle. Since our second quarter conference call we completed our new 250 million cubic feet per day Falcon plant in Permian Delaware, and the rebuild of Dock 2 at our LPG export facilities in Galena Park. Our Grand Prix pipeline continues to perform very well since commencing operations in early August. On our last earnings call, we said we expected volumes of about 200,000 barrels per day. And we exceeded those expectations averaging about 230,000 barrels per day of deliveries into Bellevue in September. We anticipate volumes to continue to improve going forward and will provide more information on 2020 volume expectations when we give our formal operational and financial guidance in February. As we think about our positioning going forward, there are some key points I like to touch on in summary, and then I will expand on as well. First, our gathering and processing business is growing and expected to continue to have strong performance even if we experience a moderation of production growth. Second, our growth is coming from primarily fee-based assets driving a higher percentage of fee-based margin and less commodity price sensitivity. Third, our continued organization-wide focus on capital discipline, largely along our core business of moving molecules from GMT transport fractionation and export is leading to more moderate capital spend going forward. And forth, our financial metrics are improving and expected to improve going forward as we benefit from our integrated platform growing EBITDA, lower CapEx and better returns. Let's talk about our gathering and processing business. Beginning in the Permian, our systems remain highly utilized as volumes across…

Thanks Matt, good morning, everyone. Targa's reported quarterly adjusted EBITDA for the third quarter was $350 million with dividend coverage of approximately one times. In our GMP segment operating margin contribution from higher sequential inlet volumes led by our Permian Midland and Permian Delaware region was partially offset by the impact of lower NGL and crude oil prices. Net and realized hedge gains third quarter GMP operating margin was about $15 million higher than our second quarter. In our logistics and marking segment operating margin sequentially increased predominantly due to a partial quarter contribution from Grand Prix. The impact of the schedule turnaround in our fractionation facilities during the third quarter was offset by the early startup of GCX. Operating expenses in our GMP segment in the third quarter decreased over the second quarter, primarily due to lower property tax estimates, while the increase in sequential downstream operating expenses, was attributable to a full quarter of transfix operations and a partial quarter of Grand Prix deliveries into Mount Belleview. Turning to hedging our percent proceeds equity commodity positions are well hedge as we continue to execute additional hedges to increase cash flow stability. We are more than 80% hedged across all commodities for the fourth quarter and more than 50% hedged across all commodities for 2020. Additional updated hedge disclosures can be found in our investor presentation. During the third quarter we recognize and unrealized non-cash Mark to market loss of $101 million associated with hedging our natural gas transportation agreement, which will be offset by underlying law and transportation gains in future. As Matt mentioned our 2019 net growth CapEx estimates for announced projects remains at approximately $2.4 billion and we have spent about $1.9 billion through the end of the third quarter, our full year 2019 maintenance CapEx…

Thanks, Jen. I'd also like to bring to your attention our inaugural sustainability report, which we published in August highlighting our framework of policies, practices, and systems in areas of safety, environmental, social and governance. We remain focused in continuing to progress our disclosures in these areas and to enhance our performance. So with that operator, please open the line for questions.

[Operator Instructions] Your first question comes from the line of Shneur Gershuni from UBS. Your line is open.

Hi, good morning, everyone. We can start off with, you know, you have Grand Prix coming online, a lot of fee-based that's coming online, and your - your fee-based component of earnings is definitely increasing. But there's also been some talk about some commercials that you and some others have had in converting percentage of proceed contracts, - to sort of bring the exposure down further. Can you talk a little bit about this? Have you had some successes? Do you expect more successes, if so, and we should be thinking about it on a go-forward basis?

Sure. So in our commodity sensitive areas, as we're going out and continuing to spend capital to hook up additional wells and facilitate growth for our producers. Given current commodity prices the returns on some of those are, you know, relatively low compared to recent points in history when you look at commodity prices. So it's not too difficult to have a discussion, you have to have them to show what our overall margins are. And we want to continue to invest for our producers. So we're adding fee-based components to those contracts. We're adding some fee floors and instances. Sometimes we're moving to - completely to fee, so it just depends on producer preferences. But we would like to see a meaningful - if not - the majority or plus of fee base to protect our investment as we go forward.

All right. Perfect. And as a follow-up question. Really pleased to see the asset sales plus that you just talked about in your prepared remarks. Do you see any more opportunities for asset sales down the road? Like, would you consider selling GCX when the DevCo presumably comes in house?

So the other asset that we named in the press release this morning was our crude business in the Midland. So that's another one that we're in the process now. We've engaged Jefferies, and we're going to look to monetize that. I think we're going to continue to look across our asset base and see what - what might be complimentary, if it's not core, and down our strategic gas value chains of gathering and processing all the way down to the export doc. We're going to have a discussion and take a hard look at it. But right now, the only one that's really on that would be the crude business in the Midland side.

Great. One final question. How much flex do you have to be towards the lower end of your growth CapEx range for 2020?

Well, I think, they sort of give a relatively narrow range, you know, as we're ramping up our internal processes for what projects we want to include and what that budget's going to look like for 2020. I think we feel pretty comfortable with that 1.2 to 1.3, and then it's really going to be when we add another processing plant in the Permian. We're going to have some spending in 2020 or does it get pushed to the end of 2020. That's what's going to really move the 1.2 to 1.3, timing of when processing is getting added. And then when we green light, you know, frac train 7 and 8 fill up. Are we ordering long lead times for train 9 and other things? So that's why I think there's a relatively tight range. And then it's just the completion of our major projects already underway, it's a majority of that.

All right? Perfect. Thank you very much. Appreciate the time today.

Okay. Thank you.

Your next question comes from the line of Spiro Dounis from Credit Suisse. Your line is open.

Good morning, everyone. Maybe starting off with 2020 growth CapEx, if you could, coming down significantly, great to see. Just curious what you think about the backlog beyond 2020? You guys have got it to aggregate CapEx at one point of about $1.8 billion between 2020 and 2021, which I guess implies maybe $500 million or $600 million in 2021. How much could we see that figure kind of change over time? Or is the right way to think about it that you maybe use any sort of excess spending capacity to bind the DevCo interest instead of new projects?

Yes, I think as we look at our capital spending trajectory, I think 2020 is a big step for us. You know, it's about half of what it was last year. So you're seeing that CapEx moderate. I think when we gave that guidance back in November of last year, the point of that was to show that going forward, the CapEx is going to be moderating significantly. I think 2020 shows that, but even in 2020, we have, you know, spending on two fractionation trains, which is higher than a normal amount of spending would be for fractionation, right? So, we plan to give annual guidance. So 2020 shows a step in the right direction, significantly moderated CapEx. Then, as we move through the year, you know, we'll give annual guidance for 2021.

It will largely be predicated on activity levels. Right, Spiro? So at this point, when we think about the assets coming online in 2020, the expectation is that they will be highly utilized relatively quickly. Train 7, we could use, you know, pretty much very quickly today. And so I think that if activity levels stay consistent with where they are today with our expectations for the near term, then obviously CapEx would be higher as a result of that. If activity levels decrease, then I think we've got more flex as we go through time to delay the timing of when we have our next plant in the Permian, either the Midland and the Delaware site, or when we would need that additional fractionation in Bellevue.

Okay, that makes sense. And just circling back on asset sales. Congrats on getting the deal done so quickly. Maybe just talk about how you think about using the proceeds. Maybe as you look at basins or assets outside of - outside of the Permian, where maybe growth is a little bit slower, where CapEx needs, I imagine, are much lower. How do you think about the valuation hurdle there to sell those assets, which I presume they're sort of free cash flow positive at this point?

Good question. We've got a lot of interest in assets across the portfolio, and we've gotten a lot of reverse inquiry around different assets. We're very pleased with the announcement this morning that we were able to successfully execute agreements on the Permian and Delaware crude side, and now we'll be evaluating the potential sale of the Permian, Midland crude assets. When you look across the portfolio beyond that, I think that everything is for sale for the right price. That's part of our jobs. But as you rightly point out, there are some areas within our system where we're spending relatively little capital, where we've been incredibly successful in reducing costs and really squeezing every last dime out of assets that we possibly can. And so getting evaluation that makes sense for us to sell those assets versus just continuing the harvest with that cash flow can be a difficult decision, but we're always open to evaluating anything that's in our portfolio.

And just to add on to that to Jen, you know where - we have been active in that market as a buyer, and as you see now, as a seller. For selling assets in the GNP, it's not a great market for that. So we're looking around that potential opportunities and what we could or could not monetize. You know, it's not a great market for that on the gas gathering and processing side.

Got it. Appreciate all that color. Thanks, everyone.

Okay. Thank you.

Your next question comes from Tristan Richardson from SunTrust. Your line is open.

Good morning, guys. Just on the 1.2 to 1.3. Sounds like there is some assumption of new project potential in that number. Could you give us a sense of buckets between, sanctioned projects and then kind of the wedge of potential projects that you've got high visibility to that aren't necessarily green lit today?

Yes. So most of that spending is related to projects that are already underway, right? Train 7, train 8, Gateway, Peregrine Export Facility. I think the reason it's relatively tight range is we do expect highly likely to be announcing another plant out in the Permian. So there will be some spending for that. And that's why we gave a range. You know, we see it is about $100 million range for depending on when we green light that plant. And then when and Y-grade volumes are increasing as a result of production activity. If we're going to have any spending or some modest amount of spending on train 9 for 2020. So those are the two, kind of, drivers to be at the high end or low end of that range.

As Matt mentioned in his prepared remarks, we are expecting growth from the producers on our systems, particularly in the Permian. And so there is a lot of spending that we're assuming will take place to facilitate their growth as they continue to drill and be successful.

Matt, I would add one other project to that and that is the extension of our Grand Prix pipeline North into Stach that is highly backed by Williams contract.

Agreed, that's another large project, thanks.

That is in there.

Helpful, thank you. And then just a follow-up as we think about the delevering cycle that kicks here and into 2021, any thoughts to updating the market on sort of long-term leverage target either you know, post year end 19 or beyond particular as we think of prospects for consolidating the debt because multiyear is out?

I think Christian that we've been consistently saying that a goal of ours is to reduce our leverage; we really let it move higher over the last couple years as we had given visibility to the ramp and cash flow and EBITDA from the project coming online. And now you're hearing us say that one of the reasons that were exploring some of the asset sales that we been successful on executing on is to more quickly to our leverage and so that's a big focus area for us. I think that because our leverage is where it is today a goal of four times consolidated over time is a reasonable assumption, but it's going to take some time to get there, just given where we are today even as our EBITDA ramps. And so we will be looking at debt co repurchase and the terms of those repurchases and our leverage as we move through time. We got great flexibility in that structure in terms of having four years from essentially the fourth quarter to take it out. So I think as we feel like we have a lot of options to use our additional cash flow as it generated.

Thank you, guys, very much.

The next question comes from Christine Cho from Barclays. Your line is now open.

Morning everyone. I wanted to start with your comments about increasing the fee-based cash flows. So when you say you're adding fee-based component and for or just outright off the, is it just for new volumes and there's nothing for existing volumes and if it is just renew volume would be fair to say that all of this contracting that you're talking about is primarily taking place in the Permian.

I would say it's a mix of new volumes and existing. So we have multiple contracts with our producers that are in different stages of life, some are relatively short term and some a longer term, but I would say it's a mix of growth volumes and existing volumes and you be corrected that most of it, I think will be taking place in the Permian but we also have some POP and some other commodity price sensitivity elsewhere, there is less activity, there's less opportunities for us to go in there and do that. We're going to those other areas as well. But it is primarily in the Permian.

Okay great and then I wanted to just talk about Waha the basis I think back out even though Grand Prix is in service. And could you just confirm that you won't be exposed to the faces to share capacity on the line and we should think that your price realization is say less the tariff you're paying for your pipeline capacity.

This is Patrick McDonie. I mean we obviously have a variety of different ways that we move gas from our assets in the Permian basis. GCX is just one of those obviously we have firm transportation on that pipeline or moving gas to [indiscernible]. We also have firm capabilities out of the basin on other pipelines. We really have a mix portfolio where we have firm sales at Waha to people with firm transportation take away. We have our own firm transport going west coming back east, going into Mexico, etcetera. So when we look across the portfolio, we feel very good about our capabilities of moving our gas a lot of it out of the basin some of it with some Waha realized price but most of that based on sales and other locations out of Waha.

Okay, great. And then just one last question, so on Grand Prix you expect September to be the hit 200,000 barrels per day and it looks like you're tracking better at 230, is this just been acceleration bit timing of volume is 250,000 barrels still the right now to hit sometime in 2020, or could this be on the conservative side and was it more a function of volumes being better on your system or third party processing plan.

Yes, I'd say when we gave the original $200,000, I'd say it was a conservative estimate. It was our first full month in service and so we wanted to make sure we felt we're going to be able to exceed that number that we gave. You saw volumes on our system sequentially increase in the Permian Midland in the Delaware, both of which helped drive some of that outperformance. I think it's a really across the board - it's across the Permian, it's our volumes and it is third party volumes as well. I think as you get into 2020, I think we - we'll give some updated volume guidance or we anticipate giving some updated volume guidance in 2020, which will include Grand Prairie. I think we feel really good about our previous $250,000 at some point in 2020. We'll be bringing that - we'll be updating that in February. But yes, we feel really good about being able to exceed that.

Great, thank you.

Okay. Thank you.

Your next question comes from the line of Michael Blum from Wells Fargo. Your line is open.

Thanks. Good morning, everyone. So you kind of broadly referenced this early in your comments, but I'm wondering if you could talk a little more directly about what you're hearing from your producer customers in various basins that you operate, just to get a feel for just how much of a slowdown do you anticipate overall or are you really not seeing it because we seem to be hearing kind of mixed messages from the midstream side.

Yes. This is Pat and I'll address that. Obviously, our biggest capital spends in the Permian Basin and our biggest growth over the past several years now has been in the Permian Basin. And obviously, we've employed a lot of capital there in the recent past, and those contracts and that activity level is underpinned by the large majors and the large independents. Certainly, we do have some smaller guys that may be more impacted by a slowdown, but generally, if you look at what we've done in the last nine months in the Delaware and Permian, we're 30% increase year on year on the nine-month look. Would we expect a 30% increase with rigs down roughly 16% year on year? Probably not a 30% increase, but a substantial increase. Our Delaware volumes obviously are coming off a smaller base. We would expect continued growth there. The activity level and the commitment of those producers is - we've got a good line of sight on them and we see that activity level being high. The Midland side, you know who our producers are; you've seen their public releases. They have drill bit committed to drilling on the Midland side of the basin, we expect robust growth there. So is there some slow down on some areas? Yes. Is it materially impacting us? Not at all. We see a lot of robust growth. And the good part about it is all of that growth really hits our fully integrated stream. It's coming through our GMP plants and it's all stuff that's going to get into Grand Prairie and down to Belleview and to our export terminal. So it looks fantastic for 2020 for us right now when we look at it.

And just to add one point to that, Pat, an increasing share of our growth is from the majors and large independents too. As the Delaware ramps and as we ramp our growth, it is increasingly tied to the major large independents who move rigs a little bit slower than some of the smaller guys.

Okay, got it. Second question is as you are adding here a fair amount of new frack capacity and expanding your LPG export dock, can you just speak to any trend in rate you're seeing there? I mean are you seeing rates hold steady? Are they going up? Down? Just wanted to get a feel for that. And then kind of related to that, if you could give us your updated views on just global LPG demand as you're around dock. Thank you.

This is Scott. And when you look at it on the frack side, we are recognizing that our expansion that we have on the frack side is supported by contracts that Pat referred to on the upstream side that is related to those larger companies, the larger independents as well. When we look at the fractionation business, it is highly supported by that in our integrated platform. It's not only feeding upstream; it's feeding through our Grand Prairie pipeline and ultimately into our frack station business and all the way down to the dock. There's been some talk of late that we have seen on the frack side, some increase in spot rates on fractionation. I would say that we are highly focused in on operating our fractionation basis around the secured contracts we have and performing for those producers in and to our frack. Even though we've seen some increases in that on a spot basis, it's not the frenzy that you saw this same time last year. And again, we are managing our inventories and looking forward to Train 7 coming online in the first quarter. And again, as Jen said in her comments, seeing that that will be highly utilized because we've got good transparency to the market in the forward months. On the export side of the business, again, we will benefit and we're already seeing benefits across our dock relative to the refurbishment of our Dock 2 that was announced - that we said that we've completed, that we'll see benefit of that in the fourth quarter, which from primarily de-bottle necks us on the butane side of our business. The market is strong. We're seeing opportunities out there. We are highly contracted today and I think we'll continue to benefit from that going forward. And again, it links us up relative to what we export across our dock as highly tied to what our fractionation growth business looks like as well as how that is tied all the way back into our GMP. And don't forget we've also got another expansion that'll be completed in the third quarter of next year, which is adding additional refrigeration, which steps us up to roughly from 10 million barrels a month today to 15 million barrels sometime in the third quarter of next year.

Great, thank you.

Okay, thank you.

Your next question comes from the line of Jeremy Tonet from JP Morgan. Your line is open.

Hi, good morning. Just wanted to pick up the comments you said earlier about getting to 80% de-based being kind of your expectation for 2020, and was just wondering if that was an average for the year or did that continue to kind of progress over the years, the rates are higher, or is there any ability to kind of keep nudging that number up? I mean it seems like that's a pretty big step change versus where TRGP has been historically. So just wanted to start there.

Yes, that 80% is an average, but we see it continuing maybe not in a straight line, but continuing up and to the right. So that fee-based percentage should just continue to increase over time. So I would expect the back half of the year to be higher fee-based percentage than earlier, but that is an annual average.

And I guess for the open exposure at this point, how do you guys think about hedging? And I'm not sure if you touched on how much you've locked in for 2020 as of now.

We're hedged over 50% across all commodities for 2020, Jeremy, and I think that we're very much focused on cash flow stability as our leverage is higher and begins to work down. And so you've seen us add a significant number of hedges really in the back half of this year, and I would expect that that would continue.

That's helpful, thanks. And just was curious if the agencies had kind of taken notice of this and how this kind of impacts your standings there, given how the business has been changing over time.

We continue to try to have a very active dialogue with the agencies, make sure there are no surprises there. So delivering on the forecast that we show them, delivering on the asset sales that we tell them we expect to have, making sure that we're just delivering on all fronts. And so that's an ongoing dialogue, and we expect that the continued growth of our business in terms of fee-based margin, asset diversity, et cetera will only help us in those dialogues.

That's helpful. That's it from me. Thanks.

Thanks, Jeremy.

The next question comes from Keith Stanley from Wolfe Research. Your line is open.

Hi. I just wanted to clarify any early thoughts on the funding plan for the CapEx budget next year. I think in the prepared remarks, you said no common equity. Should I think mainly asset sales to execute on? Would you consider preferred equity or mainly debt financing of the CapEx?

We benefit from increasing cash flow and EBITDA and have very good visibility to that, so that provides us with additional debt capacity plus more internally generated cash flow. So I think you've seen us through 2019 each quarter deliver more strongly the message just as our business has performed that we do not have expectations to need to issue any equity over the foreseeable future. As Matt said, we've got the assets that we've already executed in terms of asset sales. We've got the one that we announced this morning with the Permian Delaware crude business, and the only active asset sale other than that that's underway, which is in the early stages, is a potential sale of the Midland side of the Permian crude business. And that's really all that we're expecting at this point.

Okay. And just to clarify, the $1.2 to $1.3 billion net: is that the same of the gross number or is that the net of some of the asset sales or any project financing?

That's net of all of our partnerships so that's what Targa's expected spending is relative to all the growth projects that we have visibility to for 2020.

Okay. And then - sorry, go ahead.

Sorry. I was just going to add that it doesn't include any potential asset sales or anything like that. It's the pure spending for growth capital on projects that we have visibility to.

Okay, great. And one last small one. You said you sold the Delaware crude gathering business for I think it was $135 million. Can you just remind me the size of the Midland gathering relative to the Delaware on crude?

So, current operating margin on the Midland size of the crude business is higher than it is on the Delaware side, but we're not going to provide any more detail at this point, given we're just really kicking off the potential evaluation of the sale of the Midland crude assets.

Great. That's it for me. Thank you.

Thank you.

Our next question from [indiscernible] from Jeffries. Your line is open.

Hey, good morning, everyone. Thanks for taking my questions. Jen, I guess relative to our modeling, we saw a nice sequential improvement in the GMP operating costs this quarter, a sizable decline from last quarter. I guess I'm just curious of any additional color the drivers and the sustainability of that improvement.

I think that our operating team, particularly in the Permian where we've been spending a lot of capital and we've been bringing a lot of assets, and the service has been very much focused on reducing operating expenses, and I applaud them for those efforts. We mentioned on our second quarter call that we were putting an AGI well into service as well this summer, which is going to help reduce our chemical cost. So part of that is what you're seeing in the third quarter but this is a big area focus for us, Chris, along with capital discipline, managing our costs OpEx as well and G&A, is a big point of focus across the organization. And so this is consistent with our expectation in terms of Q3 being lower than the second quarter. The second quarter, we also had the reclass of some G&A into OpEx as well, so that was sort of more one-timey in nature. And I would expect that we will continue to remain very much focused on this, and what we're mostly focused on is having reduced per unit costs as volumes are continuing to ramp across our GMP businesses and also our downstream business.

Great. And congrats on the quick sale in Delaware. I suppose that speaks to both the quality of the asset and the banking team involved. And good luck on the Midland side. I'm curious: with those assets and those - you've mentioned some more that are pending perhaps and then the recent pull back on producer activity, how much it impacts anticipated maintenance activities in the future. Any meaningful toggle we should expect on that front?

I wouldn't expect a meaningful toggle in terms of our maintenance spending. We've also placed a lot of new assets in service, but new assets don't require a lot of maintenance. But no, I wouldn't expect that there's a big step change that's about to occur there up or down.

Okay. And then I just have one final - it's more of a clarification point on questions earlier. And Christine had asked about the fee and commodity mix of the business and efforts to grow the fee stream. I think in response to Jeremy, you said that you're still planning to hedge the open commodity exposure to ensure cash flow stability in your hedge stuff 50% for next year. Could you just remind me of any internal hurdles or targets that you have to be hedged a certain percentage at a certain time?

Our general targets, as we work with the risk committee of the board of directors is to hedge 75% for the next 12 months out, 50% for the 12 months after that, 25% for the 12 months after that. Those are the general guidelines. And then within those general guidelines on a quarterly basis we're working with the risk committee to figure out the appropriate tolerance for hedges within Targa.

Okay. But your point at this point is that those are unlikely to change even as the business become more fee, you still think that's still a good target for us to at least assume?

I think that's a fine target for now. You've seen us hedge more when we've been given the opportunity higher than those thresholds or at the same time have also hedged left in those levels when there has been something in the market that has sort of driven that decision making. So we'll continue to be flexible, but those are our targets and I don't see those changing in the near term.

Great. All right. Thanks a lot for the time this morning.

And the last question from [indiscernible] from Seaport Global Securities, your line is open.

Hi, good morning and thanks for taking my question. Couple of ones from me. Can you talk about transitioning from commodity to fee-based contracts on the POP side? I was wondering if you could talk about is there any kind of level of commodity prices with those - this transition is kind of leveling your total Targa?

When we're discussing with the producers, we're really looking at when we put capital out getting it all in return on capital. So we're targeting if we start with the fee-based contracted at what speed we need to earn an appropriate gathering and processing return on capital and that's where we start. And if they want to make the piece of that into POP or do a hybrid or floor we're flexible with all the things, we've done some of those things, it less about us agreeing on a commodity price, and where we get revenue neutral and more over range of scenarios them understanding we need to have an adequate return or at least price more protection to spend that capital.

Okay second question I had related to the lowering of OpEx in Q3 versus Q2, I think Jen mentioned some of the evaluation and on the property taxes, which helps that take down, I was wondering how frequently is that the property taxes valuation done.

Well what happens at the beginning of the year we make, an estimate on our taxes and as we move through the year and we have numbers or better visibility to numbers that we expect to be realized, we change that estimate. So generally start every year on the gathering and processing and down streaming size with our high estimate then as we move through the year and that estimate becomes again even more realize or we have more visibility to what it's going to be it tends to come down. So that's really just the pattern that we generally have year in and year out for [indiscernible] taxes.

Okay got it and then just last one for me on the export side, could you indicate what's the rough breakdown between the propane export and the beauty exports that you're seeing currently?

We have not given that it is moving more towards butane or its historically or I really need you to go back over a number of years have been kind of 8020 Scott, we been closer to 30% or even more so on butane.

We've seen that increase overtime again pointed back to the projects that we have focused in on bolt on type projects that have debottleneck around the butane side. So I think over time you will see that gradually increase with more focus on butane and that helps us also optimize on the upside, how much volume we would actually see across the dock.

You can see in our investor presentations, we provide a breakdown of the propane, butane mix of what already been loaded at the facility.

Okay, got it. Thanks guys and congrats on a good quarter.

I'm showing no further questions at this time. I would now like to turn the conference back to Sanjay Lad.

Thank you to everyone that was on the call this morning, and we appreciate your interest in Targa Resources. Please note that will be available for any follow-up questions you may have throughout the day. Thank you.

Ladies and gentlemen, this concludes today's conference. Thank you for your participation and have a wonderful day. You may now disconnect.