Good day ladies and gentlemen, and welcome to the Entergy First Quarter 2019 Earnings Release Teleconference. At this time, all participants are in a listen-only mode. [Operator Instructions]. As a reminder, today’s conference call is being recorded. I’d now like to introduce your host for today’s conference, Mr. David Borde, Vice President of Investor Relations. Sir, please go ahead.

Thank you. Good morning, and thank you for joining us. We will begin today with comments from Entergy's Chairman and CEO, Leo Denault. And then Drew Marsh, our CFO, will review results. In an effort to accommodate everyone who has questions, we request that each person ask no more than one question and one follow-up. In today's call, management will make certain forward-looking statements. Actual results could differ materially from these forward-looking statements. Management will also discuss non-GAAP financial information. Reconciliations to the applicable GAAP measures are included in today's press release and slide presentation, both of which can be found on the Investor Relations section of our website. And now I will turn the call over to Leo.

Thank you, David, and good morning, everyone. We had a productive start to the year and today, we are reporting first quarter adjusted earnings of $0.82 per share. While weather was a headwind, we remain firmly on track to achieve our full year guidance, and our longer term outlooks. We checked off every first quarter key deliverable and we added an important new milestone. We announced our agreement for a post shutdown sale of Indian Point to Holtec International. With this announcement, we now have definitive agreements to sell all of EWC's remaining nuclear assets. We will shut down program this month and we plan to close on the sale of that plant by the end of the year. We will then shut down Indian Point unit 2 next year and unit 3 in 2021. The sale of all Indian Point units is expected to close in the third quarter of 2021 and we expect to complete the Palisades transaction after it's shutdown in 2022. The sales of these plants are important, not only do they secure our orderly exit from the merchant business, but they do so in a way that benefits stakeholders by accelerating the decommissioning timeline, drawing on industry leading decommissioning and segregation expertise and experience and laying the foundation for future business development opportunities in the regions. We are grateful to our nuclear teams who remain focused on finishing strong with safe and secure operations. Our Pilgrim employees are a shining example of this hard work, commitment and dedication. In March, Pilgrim returned to normal baseline oversight by the NRC moving to Column 1 in agencies reactor oversight program. Over the last two years Pilgrim's 600 employees exhibited professionalism and pride resulting in this important milestone for our organization. At the utility business, we also executed on key deliverables in the quarter. We continue to pursue our commitment to renewable resources and two of our operating companies, Entergy Arkansas and Entergy Texas have each issued requests for proposals for 200 megawatts of solar resources. Entergy Arkansas also announced plans for a 100 megawatt solar facility. This project pending approval by the Arkansas Public Service Commission will be the largest utility owned solar facility in the state and the first to feature battery storage. The facility is expected to be in service by 2021. We are pleased with the progress we continue to make on developing renewable projects as they are an important resource beyond their obvious environmental attributes. They can provide cost-effective energy supply, fuel diversity and advance the adoption of distributed energy solutions for our customers. We currently have just over 230 megawatts of renewable resources in service including hydro, solar and biomass technologies. We also have 185 megawatts of new solar projects that have been approved and are moving forward, just under 300 megawatts that are pending regulatory approval and the 400 megawatt that I mentioned from Arkansas and Texas RFPs. And as the economics and performance of renewable resources continue to improve, we will engage with our regulators and stakeholders to expand their use across our service area. In January, we began installment of the first automated meters. Over the next three years, we will install approximately three million automated meters across our jurisdictions, with plans to activate one million new meters in 2019. The new meters will benefit our customers with faster outage identification, enhanced customer service and cost savings. Additionally, these meters will provide us with the tools to help our customers manage their energy usage and lower their bills. And we will recycle the old meters after removal. It will be sustainably dismantled yielding copper and aluminum scrap that can be recycled. Our new build CCGT projects remain on budget and on schedule. After a little over two years of construction, St. Charles power station is in its final commissioning phase and that plant is expected to be placed in service this quarter. Construction activity at the New Orleans power station kicked into high gear after the Louisiana Department of Environmental Quality issued its clean air permit. The plant will be a much needed local resource of modern natural gas generated power for residents and businesses. In Mississippi, we continue to work through the chalked out generating station acquisition to ensure that the plant is a good value for our customers. Our due diligence has identified a potential mechanical issue that may need to be addressed prior to closing. There is a possibility that closing may be delayed to allow time to resolve the issue. We will know more in the coming weeks and we'll provide an update on our next earnings call. At this point, we do not foresee a delay that will have a material financial impact. These are just a few examples of the investments we are making in our efficient and sustainable power system for the benefit of our customers. We kicked off 2019's base rate filings with Entergy Mississippi's annual FRP, which was submitted on March 15th. We are working through that process and expect new rates to be effective in June. We are also preparing to file our annual FRPs in Louisiana and Arkansas later this year. Our New Orleans rate case is ongoing and we remain on track to have new rates effective this summer and we've requested a formula rate plan to take effect next year. In addition, proposed legislation in Texas could help reduce regulatory lag on generation investment in that jurisdiction. The legislation passed the House, it was also passed by the Senate business and Commerce Committee and it will now be considered by the full Senate. If signed into law, the legislation would allow the commission to approve a rider to recover reasonable and necessary generation investment which would be more timely and less burdensome than a base rate case filing. This legislation is consistent with our desire to align regulatory structures with customer benefits. Three of our five jurisdictions, which generate approximately 80% of the utility's revenue have annual formula rate plan mechanisms. These, combined with other constructs, will allow for timely recovery of investments which benefit customers, provide clarity to our plans and solidify the financial commitments we've made to provide steady predictable growth in earnings and dividends. At Entergy, our people are critical to our success. Our employees make it possible to implement our strategy and achieve our objectives. Acquiring, retaining and developing the talent we need to meet today's business needs and to prepare for the workplace of tomorrow are important. As part of our employee focus, we are proud to promote supportive work environments for members of the National Guard and Reserve. In recognition of this, we won the 2019 Pro Patria Award from the Department of Defense and we were a semifinalist for the 2019 Freedom Award. Entergy is also committed to supporting businesses in the communities we serve. The Women's Business Enterprise National Council, recognized our efforts and once again presented the prestigious America's Top Corporations for Women's Business Enterprises award to Entergy. The national award recognizes companies with world-class diversity and inclusion programs that enable growth and innovation while breaking down barriers for women owned businesses. These awards are good validation of our mission to create value for all of our stakeholders, customers, employees, communities and owners. We recently released our annual integrated report titled, When Does One Equal More. It illustrates how our efforts to serve the needs of each stakeholder creates value for all. Our reported outlines how the emergence of new technologies enable us to build more individualized relationships with our customers and partner with them on solutions that make their lives better, and help providing opportunities for our employees to adopt new skill sets to effectively implement manage new technologies will drive transformative change. Entergy is also recognized as an industry leader for taking action to address climate issues. In 2001, we were the first U.S. electric utility to commit voluntarily to stabilizing greenhouse gas emissions. In 2005, we upped that commitment to capping our carbon dioxide emissions at 20% below year 2000 levels through the year 2010. Then in 2011, we extended that commitment through 2020. Even though, Entergy's carbon dioxide emissions rate continues to be one of the lowest among our peers, the broad consensus of current scientific data on climate change indicates that as an industry we must do more to reduce our footprint and that of our customers and communities. Entergy sees this not as a choice, but as a responsibility and an opportunity. That is why, in addition to our integrated report, we also released our climate scenario analysis and evaluation of risks and opportunities. This report outlines our role in meeting the worldwide imperative to reduce risk that's posed by climate change and announces a new greenhouse gas emissions goal to reduce our CO2 emissions rate to 15% below year 2000 levels by 2030. That means that for every unit of electricity we generate in 2030, we will emit half the carbon dioxide we did in 2000. Entergy's leadership and sustainability and social responsibility makes us a successful Fortune 500 company with a conscience. Our actions and commitments to sustainability position us to effectively benefit our stakeholders today, while securing a bright tomorrow. For the first quarter of 2019 we continue on track of steady successful execution of our strategy. And 2019 will be another successful year for us. Our operating and financial positions are solid, and our strategic direction is clear. We are an industry leader in critical measures of sustainability. We have among the lowest retail rates in the country and we operate one of the cleanest large scale fleets in the United States. We also benefit from strong industrial growth within our service territory. We invest in our employees, in our communities and our strategy is aligned with the goals of our regulators. This is what makes Entergy a compelling long-term investment. And this is the foundation from which we will continue to grow and innovate for the benefit of all of our stakeholders. I will now turn the call over to Drew, who will provide more detail on our first quarter financial results.

Thank you, Leo. Good morning, everyone. As Leo said, the first quarter was a productive start to the year and we are firmly on track to meet our full year guidance and longer-term outlook. Today, we are officially starting to report earnings using our simpler Entergy adjusted earnings measure, to better reflect the nature of our business going forward and our materials and disclosures are more streamlined as a result. Let's now turn to the numbers. As you can see on Slide four, on a per share basis. Entergy adjusted earnings were largely flat quarter-over-quarter. Turning to Slide five, results of the utility are straightforward. Net revenue increased primarily from the effective rate activity in Arkansas, Louisiana and Texas. Although the enactment of tax reform, last year's results included regulatory charges, return the benefits, the lower federal tax rates to customers. And that lower tax rate is now reflected in customer bills. Partially offsetting was lower volume due to the effects of weather, which was unfavorable this quarter compared to one year ago. Finally, a higher share count affected this quarter's results on a per share basis. EWC's first quarter results are summarized on Slide six. And as a reminder, EWC is now excluded from our Entergy adjusted measure. As reported earnings were $0.60 higher than the prior year. The key driver was strong market performance on the quarter for EWC's nuclear decommissioning trust funds. A tax item, which resulted from the sale of Vermont Yankee partly offset the increase. Before leaving EWC, I'd like to affirm that after accounting for the transaction costs for Indian Point, we still expect EWC to provide slightly positive net cash to parent from 2019 through 2022. Slide seven shows operating cash flow for the quarter of $501 million, a $56 million decrease from a year ago. The change was driven by the return of approximately $100 million of unprotected excess ADIT to customers as well as the effect of unfavorable weather. Lower pension contribution partially offset the decrease. We are affirming our 2019 earnings guidance and financial outlooks, which are summarized on Slide eight. As I mentioned, we experienced unfavorable weather in the quarter. Nevertheless, we remain on track to come in around the midpoint of our 2019 guidance. Our credit metrics are shown on Slide 10, apparent as the total debt has improved to 21.7%. This was largely due to the settlement of a portion of the equity forward in December. Our FFO to debt is 11.1%, this includes the effects of returning $692 million of unprotected excess ADIT to customers. Excluding this give back, and certain items related to our exit of EWC, FFO to debt would be 13%. We expect cash flow to improve as soon as next quarter and throughout the remainder of the year assuming normal weather. We remain committed to our targeted ranges of at or above 15% for FFO to debt at 2020 and below 25% prepared at the total debt, as well as maintaining our investment grade profile. We had a productive first quarter and we see 2019 as another successful year. The foundations in place for us to meet our financial commitments to deliver steady predictable growth in earnings and dividends through customer centric investments. As Leo mentioned, our operating and financial positions are solid and our strategic direction is clear. We're continuing our mission to create sustainable value for all of our stakeholders and look forward to the opportunities ahead. And now the Entergy team is available to answer questions.

[Operator Instructions]. Our first question comes from the line of Praful Mehta with Citigroup. Your line is now open.

Thanks so much. Hi guys.

Good morning Praful. How are you doing?

Good morning. So, I guess, first question on the earnings guide for 2019, it looks like you reduced the O&M expectation for the full year from $0.30 to $0.20. Is that -- firstly is that helping maintain your earnings guide and what's helping keep that or bring that O&M down from the original $0.30 resumption to now the $0.20?

Yes, Praful, this is Drew. That is helping us to maintain and among a couple of other things, that includes some efficiencies we found early in the year, our good operations have led to some rebates for insurance premiums. A little bit of it is timing into other periods like 2020. But, it's not enough to change in the expectations out there and we've also seen some offsets in other areas like interest expense. We had a very active quarter, in $1.5 billion of refinancing and new money issuances and since interest rates were lower we were able to capture some of that versus our previous expectation. So the combination of all those things are what's helping us maintain our expectations for the year.

Got you. That's helpful. Thanks, Drew. And then secondly on the operating cash flow drop which is significant, but it sounds like it's primarily driven by the ADIT which it seems like you front-loaded, even within the year, is that fair in terms of understanding how the ADIT will be paid out in 2019?

Yes, that's correct. That's a 12-month kind of view. And so we would see, I am talking on top of the FFO kind of measures would be a 12-month kind of view. We do see it continue to trend down over the course of the year both on the 12 month rolling bit and in the quarters and you see our operating cash flow continue to improve over the course of the year. We are about 70% done with the return of the cash, so far, to our customers.

Got you. That's super helpful. And then finally, congrats on Indian Point. Just wanted to clarify, is it fair to understand that the decommissioning trust risk or the performance of the decommissioning trust risk is now primarily in the hands of the buyer where if there is any underperformance it won't really impact the transaction economics?

That's correct.

Okay, great, thanks so much guys.

Thank you, Praful.

Our next question comes from the line of Angie Storozynski with Macquarie. Your line is now open.

I wanted to ask a longer-term question. So you mentioned that you might increase renewal part spending if the economics of wind and solar assets improve. I mean given some set of tax subsidies so those wouldn't be -- wouldn't you consider actually accelerating some of the CapEx?

I'm sorry, the connection wasn't good enough for us to catch that.

Can you hear me now.

Yes, sounds a little better yes.

I'm sorry, I was just wondering about your regulated renewable power CapEx, you mentioned that some of your jurisdictions might consider more renewable spending going forward once the renewables become more economic, but given that there is some sort of some of the tax subsidies wouldn't do you consider actually potentially accelerating this CapEx?

I'm not sure really that we would see any acceleration in those, most of these projects will be showing up at the end of the plan in the 2021 and beyond timeframe and really wouldn't see us accelerating it much. We've got to work into this. So the resource plan where they make economic sense and serve the right purpose for the grid. So as the prices come down and as the technology continues to evolve, which we fully expected to do we should see it playing a bigger role in the resource plan as it competes well with other resources for the type of operational characteristics that they have.

And I’ll just add, NCR, our low cost rates, make it a little less economic for some of these projects and of course we still have to go through the regulatory process that associated with each of these transactions. And so I think we're going at a pretty good clip, given what we think the regulatory bandwidth is at this point. Of course, if the economics took a step change, certainly we would look at something different. So we are looking at it, but we're not anticipating an acceleration like Leo said.

Okay, thank you.

Thank you.

Our next question comes from the line of Steve Fleishman with Wolfe Research. Your line is now open.

Good morning. I know you kind of addressed this. Hey, Leo, could you maybe talk a little bit more about the impacts of the Texas legislation to your plan and what -- could it be impactful to your guidance or your capital plan?

Hey, Steve, it's Rod. Good morning. The Texas legislation, while certainly positive is not material enough for us to change our guidance and outlooks. Keep in mind that it's really providing both the commission, as well as the company additional tools as we think beyond Montgomery County. So the answer to your question is not material enough in terms of financial impact to change our outlooks

Okay.

I'll add to that, Steve. It's a good risk reduction opportunity right. It aligns up the benefit that customers get from the addition of new generation with the timing of regulatory recovery. That's a lot more efficient than the way we would anticipate going about it now, our rate case around every new generating asset which works fine for something large like Montgomery County, but if you start adding smaller generation or sharing the renewable space it comes a little bit more problematic to provide that benefit to the customers at the same time you get regulatory approval.

Okay. And then just the chapter [ph] issue that you mentioned, could you remind what the investment there is and just, is there, -- is this a fixable issue or is it a risk that you just decide not to acquire the plan?

This is Drew. Our planned investment there was about $400 million including some of the upgrades and some other things that we have planned. At this point, we don't know exactly what the issue is. We just know there are some vibrations and other things, but we believe it's probably fixable, and we'll be able to get to a transaction close before too terribly long.

Okay. Okay, thank you.

Thank you, Steve.

Our next question comes from the line of Greg Gordon with Evercore. Your line is now open.

A larger question or you [Indiscernible].

Yes we can.

Sorry, I have a larger question, bigger picture question for you since these specific questions I had were just answered. We are seeing here our macro view on the U.S. economy continues to accelerate. The data just keeps getting better with the -- just notably with an absence of underlying core inflation in the economy as you guys have a particularly economically sensitive jurisdiction that is your region of the country is sort of, has a concentrated exposure to certain types of industries related to petrochemicals, et cetera. I know that you guys try to do really good job of sort of constantly evolving your thought process on underlying demand growth. Like, what is the current economic climate look like in terms of the risk of being sort of either over or under your base case demand growth expectations?

Yes, Greg, this is Drew. As we look at our industry load we continue to see positive signs, frankly. So our industrial customers are looking at a number of spreads, commodity spreads, crack spreads, gas versus oil, geographic spread between Henry Hub and yes, NBP for example or Brent and so all of those indicators continue to be green for us. Inventories are reasonable and exports are picking up as the economy -- a low nature of just energy prices here on the Gulf Coast is extremely competitive worldwide. And so, we're very confident in what we can see, our current forecast is based on what we can see from an industrial perspective. And that includes Petrochem, LNG, sub metals and not much core alkali, new at this point but core alkali has been a very strong performer for us and that market continues to get tighter. And as we look forward, we do see new opportunities in the core alkali space in the Petrochem space, there is potential for new LNG and other things. So all of that bodes well for our industrial sales expectations and while that's good for us, the really important thing for us is it gives us incremental headroom to create investments and whether it's for those industrial customers or support distribution, operations in new ways, there is significant investment opportunity within our business as we highlighted last July, so all of that industrial opportunity may create additional headroom for us to make those investments.

Right. Thank you for the detailed answer. Have a great morning.

Thanks Greg.

Our next question comes from the line of Jonathan Arnold with Deutsche Bank. Your line is now open.

Hey good morning, guys.

Good morning, Jonathan.

Can I just inquire; can you give us some -- an update on just how things are going with the discussions around Pilgrim for the transfer? There has been quite a lot of noise locally but hoping you could sort of cut through what matters for us.

This is Chris Bakken. As Leo said, we do expect the transaction to close before the end of the year. We are following very closely the license transfer application and the other issues that lead to closure and we're confident we can maintain that schedule.

Okay. And so these kind of push for an approval at the state level, do you see that as a concern or not at this point?

I think we are quite confident we can work through that. Jonathan, there isn't any state approval required in Massachusetts it's just the NRC that we're seeking.

Right I. I know, but I’ve heard some noise so people kind of pushing to have something. So it's good to hear that you don't think that's going to gain some momentum. And then just on the Indian Point similar, can you give us, is it sufficiently similar to what you've proposed elsewhere that you see this as being reasonably formulaic or any sort of special considerations to think about as you move into the approval process there and I think to comment regarding local policymakers views around New York and timing?

Well, I'll answer this particular one. From the NRC's perspective I think it should be pretty straightforward. Yes, of course, we'll be working with Holtec and the state to figure out what's the best thing to do there, but it's still early in the process and too early to tell exactly what will be required there.

Okay. Thank you. And thanks for the update.

Thank you.

Thanks Jonathan.

Our next question comes from the line of Julien Dumoulin-Smith with Bank of America. Your line is now open. Julien Dumoulin-Smith: Hey, good morning. Can you hear me?

Yes. Good morning, Julien. Julien Dumoulin-Smith: Excellent, good morning. Thank you. A lot of questions been asked already, but I wanted to come back to the Texas legislative side obviously, making good progress there, but wanted to understand a little bit the puts and takes on earned ROEs at the Texas subsidiary itself, just as you think about it perhaps, leaving aside the legislation itself, how do you think about the ability to earn your ROE, both the puts and takes over the next few years? And what -- how you think about the cadence of the benefit of legislation just year-over-year here, given the potential impact?

Hey, it's Rod. I think it's important note that the reason why we suggesting that the proposed legislation, keep in mind, it still in the midst of negotiations at the legislature, does not change our outlook in terms of Texas’s performance in large part because of the timing of the existing rate case process or rate case filing in Texas. So, we made some headway over the last several years in Texas to reduce risk to improve the likelihood of us earning our allowed ROE through mechanisms such as the transmission cost recovery rider, the distribution cost recovery rider, with the objection -- objective rather of moving Texas closer to, as Leo mentioned the other jurisdictions that have more formulaic rate mechanism. So, we view the proposed rider as a step in the right direction of reducing the risk in Texas, and improving our ability to earn and sustain our allowed ROE. So, while it's accretive structurally, it's not material enough for us to change our outlook. So putting that rider in some context, I think is appropriate. Julien Dumoulin-Smith: Got it. Okay, fair enough. Thank you. And then turning elsewhere, just wanted a quick clarifications, if you can actually, back to Andrew's question. I think if I understand you're right, you're evaluating opportunities in the renewable side, but because it's principally solar type resources rather than wind, the timing element around PPC expiration just simply doesn't jive with respect to your own efforts, in contrast to perhaps AEP's efforts in Arkansas, for instance. Again I just want to make sure I understand some of the prepared remarks that you made.

Well, certainly, we already have quite a bit happening in Arkansas, in particular, we have the wind project up and running. We have another one that's proposed and then of course, we have all the other ones that we've listed out in more detail in the materials today. So we are very focused on that. I mean, it's 1000 megawatts of renewables, that's quite a bit for us to move through all of our various jurisdictions. Like I said earlier, we will continue to keep an eye on things. If renewable started to become much more economic and the window is still open on the production or the investment tax credits certainly, we would look to accelerate if we thought that was the right thing. Julien Dumoulin-Smith: Got it. Excellent.

And just to be clear, they just fit – they’re fitting in just to the resource plan to meet needs that we have on the system including the environmental benefits and including obviously the fact that when we put these in, we get some experience with how they interact with the system, real life experience. So we're moving thoughtfully through it in a bid to benefit our customers as much as we can. Julien Dumoulin-Smith: Right, understood. Thank you for clarifying.

Thank you, Julien.

And our last question comes from the line of Charles Fishman with MorningStar Research. Your line is now open.

Thank you. Leo, you mentioned in your opening remarks that annual dividend review will occur as it regularly does in the fourth quarter. Your payout ratio, based on your guidance should be in the bottom half of your range. You have the bulk of the risk with respect in the endpoint now behind you. And then finally, your CapEx has got a little bit of a downward trajectory with some of the generation being completed. Does this put the Board in a better position to increase the dividend closer to the EPS growth rate, and I realize you can't speak for the Board, but do I least have the right factors or is there something else I am forgetting?

Well, you're correct. I can't speak for the Board at this point, but I'll just tell you, kind of a process that we go forward through. Obviously, our objective is to get to the point where your earnings and dividend growth, more closely matched than they have over the last few years. That's why we started the dividend increases long before we got into that payout ratio target. Certainly, tax reforms had an impact on that. One thing that I would say in your discussion that is not necessarily true is the capital plan reduction. If you go back to the 2013 to 2015 timeframe, that three year period, our capital plan was about $6 billion over the three years. I think the one in the presentation today is $11.7 billion. So it's a doubling of CapEx in that timeframe, while we've been able to maintain some low straights [ph] in the United States. So, we would anticipate, if we can continue to manage the business with the rate levels as attractive as they are keep customers bills low that gives us the opportunity to continue to invest more on behalf of our customers to improve technology to higher level of service at a lower price, that's our objective. So, that piece of your discussion where CapEx should be trending downward is not necessarily correct, in fact, I would think it would be going the other direction. So all those things will come into consideration. You're right on our objective is to get to the point where our earnings growth and dividend growth look more closely match, it is something that will come up within the year normally where the Board refreshes it's point of view on that and we'll take it up with them. But, actually for them, the growing capital budget, where we are in the range, where we see earnings going the opportunities associated with that will be factors that play into it.

And this is Drew, just to clarify what Leo said around the capital, we know what we showed you in July at our Analyst Day, was a capital plan that declined though, so by time we get out there we're not anticipating that would be at that level and we expect it to continue to grow.

Yes, what my mistake was I was only looking at the generation, your D is going up in that RT&D.

Yes, distribution we expect to grow with all of the investment opportunities that we have, our peers already into but we have the distribution automation, the automated meters, million going in this year, up like that which we think will begin to provide a platform for us to continue to invest into over the next several years.

Okay, thank you very much. That's all I have.

Thank you, Charles.

And that concludes today's question-and-answer session. I'd like to turn the call back to David Borde for closing remarks.

Thank you, Liz and thanks everyone for participating this morning. Our annual report on Form 10-Q is due to the SEC on May 10 and provides more details and disclosures about our financial statements. Events that occurred prior to the date of our 10-Q filing that provide additional evidence of conditions that existed at the date of the balance sheet would be reflected in our financial statements in accordance with Generally Accepted Accounting Principles. Also as a reminder, we maintain a web page as part of Entergy's Investor Relations website called Regulatory and Other Information, which provides key updates of regulatory proceedings and important milestones on our strategic execution. While some of this information may be considered material information, you should not rely exclusively on this page for all relevant company information. And this concludes our call. Thank you very much.

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