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Avista Corp (AVA 0.59%)
Q1Â 2019 Earnings Call
May. 02, 2019, 10:30 a.m. ET
Contents:
- Prepared Remarks
- Questions and Answers
- Call Participants
Prepared Remarks:
Operator
Welcome to the Q1 2019 Earnings Conference Call. My name is James. I'll be your operator for today's call. At this time, all participants are in a listen-only mode. Later, we will conduct a question-and-answer session. (Operator Instructions). And also note this conference is being recorded. I now like to turn the call over to John Wilcox, Investor Relations Manager. John, you may begin.
John Wilcox -- Investor Relations Manager
Thanks, James. Good morning, everyone, and welcome to Avista's First Quarter 2019 Earnings Conference Call. As an introduction, I've been with the Avista since 2001, and I've spent most of my time with the company in SEC reporting and energy resources accounting. I'm a proud University of Washington graduate, and I'm excited for my new role. Our earnings were released pre-market this morning and our first quarter 10-Q was filed on Wednesday. They're both available on our website. Joining me this morning are Avista Corp. Chairman of the Board and CEO, Scott Morris; Senior Vice President and CFO, Mark Thies ; Vice President, External Affairs and Chief Customer Officer, Kevin Christie; and Vice President and Controller, Ryan Krasselt.
I would like to remind everyone that some of the statements that will be made today are forward-looking statements that involve assumptions, risks, and uncertainties, which are subject to change. For reference to the various factors which could cause actual results to differ materially from those discussed in today's call, please refer to our 10-K for 2018 and 10-Q for the first quarter 2019, which are available on our website.
To begin this presentation, I would like to recap the financial results presented in today's press release. Our consolidated earnings for the first quarter of 2019 were at $1.76 per diluted share compared to $0.83 for the first quarter of 2018. Now, I'll turn the discussion over to Scott.
Scott L. Morris -- Chairman and Chief Executive Officer
Thank you, John, and congratulations on your new role as the Manager of Investor Relations. I'm excited that we recently announced the goal to serve our customers with 100% clean electricity by 2045 and to have a carbon-neutral supply of electricity by the end of 2027. This commitment bolsters our long-standing history of providing clean, reliable and affordable energy to the customers and communities that we serve. We announce this 100% clean electricity goal as an important step forward in caring for our environment while continuing to meet the energy needs of our customers and communities today and well into the future.
We've already begun working toward our goal because in the last three years we've implemented three renewable energy projects on behalf of our customers, two solar projects and one wind project all located in Washington State. In addition, last wee we announced an agreement with a California independent system operator to participate in the Western Energy Imbalance Market, which furthers our commitment to integrate renewable energy into our electric generation resource mix. We expect to begin implementing new processes to enable participation in the EIM in the second half of 2019 and we expect to be full participants in the market by April 2022.
In late April, the Washington State legislature passed Senate Bill 5116. The bill establishes three standards applicable to us. First, on or before December 31, 2025 we'll no longer be allowed to use output from Colstrip to serve loads in Washington. Second, by January 1, 2030, we must serve no less than 80% of our load with conservation and renewable and non-emitting generation. And three, by January 1, 2045, we must serve our entire load with renewable and non-emitting resources. The legislation also contains provisions that we believe provide the Washington Commission tools for constructive regulatory decisions that may allow us to reduce regulatory lag while providing more future rate certainty for customers.
With regards to our quarterly results, our consolidated earnings were below our expectations for the first quarter. However, we remain on track to meet our guidance for the full year. Our first quarter 2019 earnings were positively impacted by the receipt of the termination fee from Hydro One.
AEL&P and our other businesses each had a good start to the year. In addition, we're excited to announce that during April, we sold our subsidiary METALfx for the net proceeds of about $17 million and we expect to recognize a net gain of about $2.4 million during the second quarter of this transaction. We want to thank the entire team at METALfx as it has been great to work with them over the past 20-plus years, and we wish them well into the future.
Regarding regulatory matters, on April 30, we filed general rate cases in Washington that our two-year rate plans, if approved, the electric general rate request is designed to increase annual base revenues by $45.8 million effective April 1, 2020 and $18.9 million effective April 1, 2021. For natural gas, if approved, the general rate case is designed to increase annual base revenues by $12.9 million effective April 1, 2020 and $6.5 million effective April 1, 2021. The electric and natural gas rate requests are based on our proposed rate of return on rate basis 7.52% with a common equity ratio of 50% and a 9.9% return on equity. We also filed general rate cases in Oregon in March, and if approved, the request is designed to increase annual based revenues by $6.7 million. The request is based on our proposed rate of return on rate basis 7.55% with a common equity ratio of 50% and a 9.9% return on equity. We are evaluating filing in Idaho in the second quarter. The purpose of all our general rate cases, our requests, is to recover the costs associated with our capital investments to replace aging infrastructure and for reliability, resiliency, and technology improvements. So now, I'll turn it over to Mark.
Mark Thies -- Senior Vice President and Chief Financial Officer
Thanks, Scott, and good morning everyone. You know, with my normal Blackhawks comment, we didn't make the playoffs for our second year in a row. But to make -- pour salt on the wound, when we go down to AGA I will have to wear a garish New York Rangers tie, so that's going to really hurt. So if I see any of you down there, please don't comment.
For the first quarter of 2019, Avista Utilities contributed a $1.70 per diluted share compared to $0.84 in 2018. The increase in earnings for the first quarter was primarily due to the receipt of the termination fee as Scott mentioned from Hydro One as well as a positive impact from general rate cases and customer growth. The increases were partially offset by transaction costs and taxes associated with the terminated acquisition, increased net power supply cost, transmission and distribution operating and maintenance costs and depreciation and interest.
The ERM(ph) in Washington was a 2.5 million pre-tax expense in the first quarter of '19 as opposed to a $4.9 million pre-tax benefit in the first quarter last year.
With respect to capital, we continue to remain committed to invest in the necessary capital to maintain the vibrancy of our utility infrastructure. We expect the Avista Utilities' capital expenditures to total about $405 million in 2019. As of March 30, we have $220 million of available liquidity under our committed credit lines at Avista Utilities, and in 2019, we expect to issue approximately $165 million of long-term debt and that includes repayment on a $90 million maturity we have later in the year and up to $50 million in equity in order to refinance maturing long-term debt, fund our planned capital expenditures and maintain an appropriate capital structure.
With respect to guidance, as Scott mentioned earlier, we're confirming our 2019 guidance for consolidated earnings to be in the range of $2.78 to $2.98 per diluted share, which includes $1.01(ph) per diluted share related to the termination fee and the payment of remaining transaction costs. We anticipate continued regulatory lag during 2019 through 2021. And as Scott mentioned, we filed rate cases in Washington and Oregon and our evaluated filing in Idaho in the second quarter. We expect these cases to provide rate relief in early 2020 and to begin reducing this regulatory lag. Going forward, we expect to continue to reduce that lag and get our authorized returns back to earning our authorized level by 2022. To achieve this, we anticipate annual earnings growth rate of 9% to 10% from 2020 and 2022 with a return to normal 4% to 5% growth rate following 2022. The growth rates are based on the midpoint of our 2019 earnings guidance as the starting point excluding the $1 per diluted share related to Hydro One. These growth rates also assume timely and appropriate rate relief in all of our jurisdictions.
Our 2019 earnings guidance range encompasses unrecovered structural costs, estimated return on equity by approximately 90 basis points. And in addition, our range also includes regulatory timing lag of approximately 105 basis points. This results in an expected return on equity for Avista Utilities of 7.5% in 2019. We expect Avista Utilities to contribute in the range of $2.72 to $2.86 per diluted share, again, including $1 related to the Hydro One cost net of transaction cost. The midpoint of our guidance at Avista Utilities does not include any expense or benefit under the ERM. Our current expectation for the ERM is a benefit position in the 75% and 25% band which is expected to add approximately $0.05 per diluted share. This is a reduction of about $0.02 per diluted share from our call at the end of the year in February.
Our outlook for Avista Utilities assumes among other variables normal precipitation temperatures but below normal hydroelectric generation for the remainder of the year. For 2019, We expect AEL&P to contribute in the range of $0.09 to $0.13 per diluted share, and our outlook for AEL&P assumes, among other variables, normal precipitation and hydroelectric generation for the remainder of the year. We expect other businesses to be between a loss of $0.03 and a loss of $0.01 per diluted share which includes the costs associated with exploring strategic opportunities. Our guidance includes only normal operating conditions and does not include unusual items such as settlement transactions or acquisitions and dispositions until the effects are known and certain.
I will now turn the call back over to John.
John Wilcox -- Investor Relations Manager
And now we will open up this call for questions.
Questions and Answers:
Operator
Thank you. We can begin our question-and-answer session. (Operator Instructions) Our first question is from Andrew Levi of ExodusPoint.
Andrew Levi -- ExodusPoint -- Analyst
Hey, I never get the first question.
Scott L. Morris -- Chairman and Chief Executive Officer
Well, you did this time, Andy.
Andrew Levi -- ExodusPoint -- Analyst
Might be the only one. So how are you guys doing?
Scott L. Morris -- Chairman and Chief Executive Officer
Good.
Andrew Levi -- ExodusPoint -- Analyst
By the way your new IR director was very, very helpful to us, so just FYI on that.
Scott L. Morris -- Chairman and Chief Executive Officer
That's good.
Andrew Levi -- ExodusPoint -- Analyst
Good choice. I just wanted to go over a couple things. I guess, just first, I mean, so this year I kind of understand. As you get into next year, I guess, as I kind of built my model, I was getting a little confused on the 9% to 10% for 2020, relative to off of the 2019 number. So just a couple of questions around that. Are you guys assuming that you get your full ask in the three jurisdictions or is there another assumption in that 9% to 10%?
Scott L. Morris -- Chairman and Chief Executive Officer
No. Andy, historically, we have never gotten everything full ask that we've ever asked for. There's a -- you can go back historically and will get a varying range between maybe 50% and 70% and it just depends on where we are with different things. But the Commission does their work and they cut back some of that from our full ask. But -- so our expectations are what our expectations are, we don't put the full ask. We put what we expect to get in our forecast and in our guidance. That's why we give you the range of the guidance and the midpoint of where we're starting from. And then it's just math from your perspective, but we don't give you the breakdown of what assumptions are by jurisdiction or by service. It's just included in the total.
Andrew Levi -- ExodusPoint -- Analyst
Got it. Okay. And then I guess kind of just around that as well. When you came out with the 9% to 10%, again 20% and 21%, did that assume that rates would only begin in April of each year because the first quarter is like 40% or something like that of your total earnings? And so, you're not going to capture that in the rate increases in '20 and then the second step in '21. And I'm wondering if that was incorporated or that could end up being --
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Scott L. Morris -- Chairman and Chief Executive Officer
Yes. All that's incorporated and that's really just solely for Washington, which is our largest jurisdiction.
Andrew Levi -- ExodusPoint -- Analyst
I understand.
Scott L. Morris -- Chairman and Chief Executive Officer
Should we file in Idaho, historically, those have gone into effect on January, and Oregon will be close. We filed in March, so we should be close to January for a rate increase and assuming again the Commission improves it and we go through that process, so it's really Washington that's the one that's in April.
Andrew Levi -- ExodusPoint -- Analyst
Right.
Scott L. Morris -- Chairman and Chief Executive Officer
And that's just where it'll be. So, yes, that would cause some of that lag as we start.
Andrew Levi -- ExodusPoint -- Analyst
Okay. So I am just -- OK. I guess I'll have to speak to IR again and figure that out because O&M is suppose to grow, what, 2% to 3% a year. Is that right?
Scott L. Morris -- Chairman and Chief Executive Officer
Yeah, around inflation, that's what we look at, historically.
Andrew Levi -- ExodusPoint -- Analyst
Okay. And then you have 90 basis points of structural lag, is that what you said?
Scott L. Morris -- Chairman and Chief Executive Officer
Yes.
Andrew Levi -- ExodusPoint -- Analyst
Okay. I think I got all the numbers right. Okay. And then just as far as this year, the last question on the first quarter, you mentioned it was below your expectations on this one and what your expectations were for the quarter?
Scott L. Morris -- Chairman and Chief Executive Officer
Well, the powers, we don't give quarterly guidance, Andy.
Andrew Levi -- ExodusPoint -- Analyst
Right.
Scott L. Morris -- Chairman and Chief Executive Officer
So -- but if you look at it, just just looking at where the ERM was, it came in a lot lower. We had lower hydro and that was more -- it stayed, it stayed colder in the mountain, so we didn't get the runoff in the first quarter. We expect our hydro to be about 93% for the year. So we do expect our hydro to be off a little bit. And gas prices were higher in the first quarter due to colder weather and some problems in moving gas in our part of the country. So we were off in the first quarter about $0.09 cents. But for the year, we expect to be just $0.02 cents different in the ERM.
Andrew Levi -- ExodusPoint -- Analyst
Okay.
Scott L. Morris -- Chairman and Chief Executive Officer
We still expect to be positive in the ERM $0.05 than we were last quarter when we provided guidance, we expect it be $0.07 positive. So we do expect in our forecast to just be off $0.02 from that.
Andrew Levi -- ExodusPoint -- Analyst
Got it. I'll let someone else go assuming there is someone else. Thank you very much.
Scott L. Morris -- Chairman and Chief Executive Officer
Thanks, Andy.
Operator
Next question from Chris Ellinghaus of Williams Capital.
Chris Ellinghaus -- The Williams Capital Group -- Analyst
Hey, guys, how are you?
John Wilcox -- Investor Relations Manager
Hi Chris.
Scott L. Morris -- Chairman and Chief Executive Officer
Hi Chris.
Chris Ellinghaus -- The Williams Capital Group -- Analyst
Scott, can you just talk about the METALfx transaction and what led to that, what was the rationale?
Scott L. Morris -- Chairman and Chief Executive Officer
You know, I'll let Mark do that because he led the team on that and deal and he did a great job. So, Mark, why don't you go ahead and take that.
Mark Thies -- Senior Vice President and Chief Financial Officer
Thanks, Scott. So, Chris, it was really a couple of things. It was a non-core asset and we had long worked with the leader there Gordon Short who's been the president and run that for almost 20 years. Gordon was getting ready to retire; we had targets to get to a certain level; and then we felt it made sense to exit and redeploy that capital into other things that made sense for us and this was just the time to do that. So it worked out. We had a good process and the team is set up to continue to grow and run that business, and we'll get the capital and redeploy it into our other businesses. So it's just the time was right for us to sell it.
Chris Ellinghaus -- The Williams Capital Group -- Analyst
And with that $2.4 million gain part of the original guidance?
Mark Thies -- Senior Vice President and Chief Financial Officer
No, we don't we don't include acquisitions or dispositions in that. So that would be additional. That'll be included in our guidance. We're not changing, that's all within a range.
Chris Ellinghaus -- The Williams Capital Group -- Analyst
Right. Also, the one of the things that surprised me in the quarter is when I was keeping an eye on precipitation in Spokane, it looked like it was a little bit above normal. So with your sort of below normal hydro, was that a function of the type of precipitation or different kinds of precipitation and different tributaries. What is the difference between what I could see visibly on precipitation and which your hydro conditions were?
Mark Thies -- Senior Vice President and Chief Financial Officer
Again. You know, it's also when it melts, right. If it's coming as snow and not rain, it's staying up in the mountains. And it doesn't really matter as much, you know, Spokane is about 20% of our generation and then the Clark Fork is 80% of our own generation. So it really matters more there. And in the current forecast, like I said earlier, when I was opening, we expect to be about 93% hydro. So we were off in the first quarter because it actually was cold in February and it stayed up in the mountains. It didn't melt and didn't come down in the first quarter as it normally does. Again, first quarter is not a significant quarter for hydro. It's really second quarter that is, but it all depends on how it melts. And so we expect to be down and that's all included in our forecasts and our expectations for the ERM.
Scott L. Morris -- Chairman and Chief Executive Officer
And, Chris, I would just add if you recall it was -- we had kind of a warmer drier December-January. We had a great February. March was cold, but there wasn't as much precip in March, quite as much as normal. So February was great, but from overall perspective, the region is down a little bit on precip.
Chris Ellinghaus -- The Williams Capital Group -- Analyst
Okay. Great. Thanks. I appreciate it. Go Rangers.
Operator
Okay. Our next question from Shar Pourreza of Guggenheim.
Constantine Lednev -- Guggenheim Partners -- Analyst
Hi, good morning. It's actually Constantine here for Shar, had to shuffle through a couple of calls. How are you guys?
Scott L. Morris -- Chairman and Chief Executive Officer
Okay, good morning.
Constantine Lednev -- Guggenheim Partners -- Analyst
And just a quick question to follow up a little bit on kind of the modeling and some higher-level ideas. So you mentioned that there is about 200 bps of kind of lag between structural and something that's more of a timing nature. So the current rate case that's filed in Washington, that kind of closes the gap to that number. And that's the two-year plan that takes you through the 9% to 10% EPS growth. And then, I guess, the question just to confirm that and the question would be, so would the new kind of regulatory advances through the bill, through the SB 5116, is there any way to think about how that would change in the future kind of once that gets implemented, once that kind of Commission, if you go back to the Commission with some of these rules, are there, is the 200 bps the right way to think about the lag?
Scott L. Morris -- Chairman and Chief Executive Officer
You're rounding, it's 90 basis points of structural lag and and really when we file our rate cases that's not, you know, we're not, that's a structural component that doesn't get affected by the rate cases. The 105 basis points is what we're really filing to reduce when we file our rate cases.
Constantine Lednev -- Guggenheim Partners -- Analyst
Right.
Scott L. Morris -- Chairman and Chief Executive Officer
And, yes, we do expect as we get, you know, work through the commission process and get orders in Washington and Idaho -- Washington and Oregon, and if we choose to file in Idaho and Idaho as well, that that would help reduce that lag over the next couple of years, and it would be, you know, would be part of that. So that is correct and that is our expectation. And with respect to Senate bill, the Senate bill, I'll turn it over to Kevin Christie to talk about that.
Kevin Christie -- Vice President, External Affairs and Chief Customer Officer
Good morning. This is Kevin here. Yeah, we believe the Senate bill from a rate or regulatory perspective offers support for us and our ability to reduce regulatory timing lag. It expressly acknowledges the Commission's existing authority to approve multi-year rate plans and other flexible mechanisms. It provides the Commission authority to allow for the recovery of costs, property which becomes used and useful during the period of up to 48 months after rates have been approved. So between those two components, that gives us the support from the Commission a chance of moving up to earn our authorized return.
Constantine Lednev -- Guggenheim Partners -- Analyst
Okay. And a quick follow up on the bill as well. How are you guys thinking about the power purchase agreements return, so that -- I know that there were some language in the bill around that?
Kevin Christie -- Vice President, External Affairs and Chief Customer Officer
Yeah. We have the opportunity to the extent that we sign a PPA going forward, so future PPAs to earn on the cost of that PPA, the costs that we're incurring as the PPA plays out over time, and that's at our weighted average cost to capital.
Constantine Lednev -- Guggenheim Partners -- Analyst
And the cost that's being incurred is kind of just the overall kind of level at which PPA is being signed, right?
Kevin Christie -- Vice President, External Affairs and Chief Customer Officer
Yeah, exactly on the expense.
Constantine Lednev -- Guggenheim Partners -- Analyst
Okay. And, I guess, the last one. Given the regulatory and legislative developments in Washington, how do you view kind of the projected CapEx but, potentially, beyond kind of '22 as some of the targets start approaching for kind of 25(ph) in terms of replacement of capacity and implementation of energy efficiency and the clean energy programs, how are you thinking in terms of the CapEx and the rate base profile?
Scott L. Morris -- Chairman and Chief Executive Officer
Well, one thing, I'll let Mark talk a little bit about that too. But I would just say that we have a very robust integrated resource planning process where we're going to be looking at what best fits our customers for from a, you know, whether we build it, whether we do PPAs, how we focus on conservation, what we need from both the energy and a capacity perspective. So there's a lot to think about. We've got a great team that's looking at that, and we're confident we'll be able to address all of those needs and do it in the best, most cost-effective, affordable way for our customers and what's best for the region. So we don't have exact plans beyond 2022 right now. We're still in the planning process but we're confident that we'll be able to meet the needs.
Constantine Lednev -- Guggenheim Partners -- Analyst
And that process -- well, what's the timeline for kind of starting that process once the kind of the bill and all the new targets gets that(ph)?
Scott L. Morris -- Chairman and Chief Executive Officer
Well, we do integrated resource planning every other year, so we are in the midst of that planning right now. And as we get through our integrated resource planning process, we'll put together a 20-year forecast of how best to meet those needs. And we have both a near-term and a long-term plan and then we execute around those plans.
Constantine Lednev -- Guggenheim Partners -- Analyst
Okay. Perfect. That answers all my question. Thank you, guys.
Scott L. Morris -- Chairman and Chief Executive Officer
Thank you.
Operator
Next question from Vedula Murti of Avon Capital.
Vedula Murti -- Avon Capital -- Analyst
Good morning.
Scott L. Morris -- Chairman and Chief Executive Officer
Good morning.
Vedula Murti -- Avon Capital -- Analyst
I'm wondering now, you filed the rate case in Washington as a two-year proposal. I'm wondering given that's a two year proposal and having that flexibility going forward, it doesn't appear though at least right now that having that ability is going to compress the time period over which the current lag of 105 basis points would be addressed. It sounds like it's more of something that once you are able to true that lag up post 2022, that in the future that that lag simply -- will have the opportunity to not recur to be minimized, is that the right way to think about it?
Scott L. Morris -- Chairman and Chief Executive Officer
I don't -- I'm not exactly sure I understand, Vedula, what you're saying. We're filing in the rate cases that we expect to reduce our lag over time. Some of that lag by the fact that, as mentioned earlier on the call, that in Washington our largest jurisdiction we won't, in the first year, have the opportunity to have rates go into effect prior to April 1. And with the first quarter being one of our larger quarters in a year, we do expect to have continuing lag in 2020, and we may not get everything we asked for, so it may take some time in that 2020 time frame. And the Commission, we have to work with the Commission and all the parties to get that into effect. So that could be spread over those two years and then we also have the opportunity in 2022 to have another case filed at the end of the two-year plan. So it's a combination of things. If we get treatment that is more favorable early, we can reduce the time frame of that lag. If we -- but we don't, we're not, what we are anticipating is by 2022 we'll have our opportunity to get that lag to zero of the 105 basis points, and we will continue to work to make that sooner if possible. But that's not our expectation in our guidance.
Vedula Murti -- Avon Capital -- Analyst
Okay. And are there any specific items, and there were some discussion about the IRP and some other things in terms of that we ought to pay attention to that could be a material uptick too, I think it's $405 million approximately CapEx run rate that you currently have through to 2020 to time frame?
Scott L. Morris -- Chairman and Chief Executive Officer
I would say not in the near term. I think those are much more longer-term items that we may have opportunities for looking at our capital and we'll look at that, but in the near term, I wouldn't. I would look through 2022 and expect us to continue to spend our $405 million of capital at Avista Utilities as well as the capital we spend at Alaska in our other businesses.
Vedula Murti -- Avon Capital -- Analyst
Okay. Thank you.
Scott L. Morris -- Chairman and Chief Executive Officer
Thank you, Vedula.
Operator
(Operator Instructions). Question from Chris Ellinghaus of Williams Capital again.
Chris Ellinghaus -- The Williams Capital Group -- Analyst
Hey, guys, one more thing on SB 5116, it seems to be encouraging of acquisition of resources. Did you interpret it that way as well?
Kevin Christie -- Vice President, External Affairs and Chief Customer Officer
Hey, Chris, this is Kevin Christie again. It's simply providing for that possibility to the extent but that's what makes the most sense as we move forward with our resource planning and the opportunity to keep costs as low as possible for our customers.
Chris Ellinghaus -- The Williams Capital Group -- Analyst
So do you see the language of the bill being incrementally an opportunity along the acquisition front?
Kevin Christie -- Vice President, External Affairs and Chief Customer Officer
Sure, it is in the sense that we would be able to earn on the PPA or EPA and that wasn't possible in the past. So that is an opportunity.
Chris Ellinghaus -- The Williams Capital Group -- Analyst
Okay. Thanks a lot.
Scott L. Morris -- Chairman and Chief Executive Officer
Thanks, Chris.
Operator
(Operator Instructions). It looks like we have no more questions.
Scott L. Morris -- Chairman and Chief Executive Officer
I would like to thank everyone for joining us today. We certainly appreciate your interest in our company. Have a great day.
Operator
Thank you, ladies and gentlemen. This concludes today's conference. Thank you for your participation. You may now disconnect.
Duration: 31 minutes
Call participants:
John Wilcox -- Investor Relations Manager
Scott L. Morris -- Chairman and Chief Executive Officer
Mark Thies -- Senior Vice President and Chief Financial Officer
Andrew Levi -- ExodusPoint -- Analyst
Chris Ellinghaus -- The Williams Capital Group -- Analyst
Constantine Lednev -- Guggenheim Partners -- Analyst
Kevin Christie -- Vice President, External Affairs and Chief Customer Officer
Vedula Murti -- Avon Capital -- Analyst
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