Algonquin Power & Utilities Corp. (AQN) Q3 2018 Earnings Report, Transcript and Summary

Thank you for standing by. This is the conference operator. Welcome to the Algonquin Power & Utilities Corp. Third Quarter 2018 Conference Call. As a reminder, all participants are in listen-only mode, and the conference is being recorded. After the presentation, there will be an opportunity to ask questions. [Operator Instructions] I would now like to turn the conference over to David Bronicheski, Chief Financial Officer. Please go ahead, Mr. Bronicheski.

Thank you. Good morning, everyone. And thanks to everybody on the line today for joining us for our 2018 third quarter earnings conference call. As everyone knows, Chris Jarratt, our Vice Chair, would typically introduce this call, but Chris today is attending an Atlantica board meeting across the pond on Algonquin’s behalf. So, today, you’ve got Ian Robertson and myself copiloting today's conference call. To accompany this earnings call, we also have a supplemental webcast presentation that you can access from our website, algonquinpowerandutilities.com. This presentation as well as additional information on our Q3 2018 results is available for download from our website. Before continuing with the call, we’d like to remind you that our discussion during this call will including forward-looking information and may also refer to certain non-GAAP financial measures. At the end of this call, member of our Investor Relations team will read a brief legal notice in respect of both forward-looking information and non-GAAP financial measures. On our call this morning, Ian will outline the operational and development highlights of Q3 2018. I'll follow up with financial highlights for the quarter. And then, Ian will conclude with our outlook for the remainder of 2018 and beyond. We will then open the lines for questions as usual. We just ask that you restrict your questions to a maximum of two and then requeue, if you have additional questions to allow others the opportunity to participate on the call this morning. Now, I will turn things over to Ian to discuss our progress on Q3.

David, thanks very much. I appreciate it. Welcome everyone to our Q3 earnings call. As usual, let’s start the call by highlighting a few of the key takeaways from across our business this quarter. Firstly, despite challenging natural resource conditions, which brought lower than average wind and solar in the quarter, which actually seems to be somewhat of a sector theme this quarter, the diversification of our business groups helped us deliver stable financial results in the quarter. Adjusted EBITDA continues to show growth over the comparable quarter in 2017. Adjusted funds from operation increased by 22%. And our adjusted earnings per share appears to be consistent with consensus estimate. Secondly, we continued to build positive momentum on our investment initiatives in Q3. We’re making progress on our efforts to reduce energy bills for our electric customers by bringing 600 megawatts of new renewable energy into Liberty Utilities Midwest, generating that following finalization of agreement for the construction of the wind generating capacity comprising our customer savings plan, final CCN and or Certificate of Convenience and Necessity regulatory docket for two of the three projects comprising the 600 megawatts have been opened in Missouri with the remaining application scheduled to be completed in the coming days. Based on the procedural schedule, which has been discussed, final approvals are expected early this coming year. Looking north of the U.S. border, in mid-September, we were pleased with the receipt of the environmental approvals of the government of Saskatchewan for our 177 megawatt Blue Hill wind project. So, it is an important milestone in the development of this material size Canadian project. And lastly, we continue to advance our diverse, high-quality set of growth opportunities. Within Liberty Utilities, our $300-plus-million Granite Bridge natural gas transmission and storage infrastructure project continues to be recognized as a prudent initiative to reduce the energy costs for our New Hampshire natural gas customers by helping alleviate New England supply constraints. Consistent with our organization's commitment to sustainability, we’re pleased that a regulatory approval document has now been open to approve our first renewable natural gas production facility. The ability to offer our customers the opportunity to use renewable natural gas to help them meet their own environmental sustainability goals was an important factor in Liberty Utilities recent success in attracting a new, large institutional customer in New Hampshire. Next, with the condition precedent to closing merely satisfied, we expect closing of the transaction pursuant to which Algonquin will acquire an additional 16.5% interest in Atlantica to occur in the quarter. And finally, within AAGES, our international infrastructure development arm, we are pleased with the execution of the agreements needed to allow development of the 220 kilometer ATN3 transmission line in Peru to move to the next stage with an understanding now reach with the existing project lenders. Obtaining the concession agreement of Peruvian government is the next step before construction resumes. And with that, I’ll pass it back over to David for a review of our Q3 2018 financial results. David?

Thanks, Ian, and good morning, again, everyone. As Ian mentioned earlier, Algonquin Power continued to deliver strong and predictable results in Q3 of this quarter. Year-over-year, our adjusted EBITDA was a $164.2 million, and that was a 4% increase over the comparable period in 2017. Further, because of our strong growth profile, we continued to show overall growth in our EBITDA on a consolidated basis, even as we absorbed the effects of U.S. tax reform. Within our Liberty Power business, the overall EBITDA increase over the comparable quarter was largely driven by a full quarter of results from our Great Bay solar facility, representing $2.1 million, and our Q3 dividend from Atlantica of $8.4 million, partially offset by less than seasonal production from our hydro facilities and lower HLBV from our U.S. wind facilities. On a net basis, Liberty Power was certainly a growth driver for us in Q3. On the Liberty Utilities side of our business, EBITDA contribution from the utilities business was essentially flat compared to a year ago. There were two factors at work here. First, from a pure operations perspective, contributions from our electric operations improved over the results in Q3 2017 due to warmer weather and higher cooling degree days, but this was partially offset by lower consumption and higher operating costs within our gas business. Second, from a rates perspective, as we expected, we see the value of our regulatory diversity at work. Given we operate 37 utilities in 12 regulatory jurisdictions, we always have several rate cases that are in front of regulators at any given time. So, we see the implementation of new rates at a number of our utilities, largely offsetting the net effects of U.S. tax reform. As a result, EBITDA from our utilities group was essentially flat year-over-year. I would also mentioned that late in the quarter, we received our rate order from the Missouri PSC with respect to tax reform which we have implemented beginning August 30, 2018. As a result, we've now received and implemented rate orders for U.S. tax reform to more than 90% of our utility customers. The rate orders that we have received and implemented in 2018 continue to be consistent and within our expectations of the overall effects of U.S. tax reform which we communicated earlier in the year as being approximately 3% or 5% of our 2018 EBITDA. This amount is certainly within the normal operating variability through which we manage our business. With respect to EPS, we reported adjusted EPS of $0.10 for Q3 2018, which is consistent with market expectations. Our adjusted EPS was less than 2017 due to lower HLBV income and a rate order which created a onetime increase to our regulated depreciation expense. The final item I would like to mention this morning relates to our recent issuance of subordinated notes to U.S. institutional and retail investors, which was completed subsequent to the end of Q3. Shortly after the quarter-end, we had a very successful offering in the U.S. public debt capital markets. This marked our inaugural entry into the U.S. public debt markets. We launched the $200 million public subordinated debt offering, which due to demand, we upsized to a total of $287.5 million. This was a 60-year non-call 5 fixed-to-floating subordinated note with a coupon of 6.875%. These notes are now trading on the New York Stock Exchange under the symbol AQNA. With that, I'll turn things back over to Ian.

Thanks, David. Finally, before we open up the lines for questions in a couple of moments, I thought that rather than, as usual, walking through our near-term growth initiatives, which actually I think are pretty well-covered in the MD&A, I provide a sneak peek at the themes for our upcoming Investor Day. Firstly, we see our commitment to operational excellence as a source of value creation. You'll hear about our local focus contributing to improve regulatory mechanisms. This commitment to understanding and delivering against our customer needs is our path to success for the utility of the future. Lastly, the falling price of energy makes operational excellence an increasingly critical success factor in the renewable energy value proposition. The second theme that you'll hear about is what began as a small investment in solar energy in our California utility, has now expanded to represent well more than a $1.5 billion of forecast CapEx in our five-year Liberty Utilities investment plan. We believe that advances in energy storage coupled with California's commitment to renewable energy will support our objective of making a 100% renewable energy utility a near-term reality. Technological and economic advances are allowing our natural gas utilities to offer renewable natural gas to our customers, an important contributor to helping our customers meet their own environmental sustainability objectives. And the last theme you'll hear about is that we believe our entrepreneurial and agile culture will be critical to help integrate sustainability into our business plan and strategy, and put us on the path to doing well and doing good. The continual decline in renewable energy prices is driving growth in the Liberty Power pipeline of wind and solar projects, leading up to the expiration of the production tax credits in the United States. New opportunities to modernize our utility operations and introduce new technology solutions to provide enhanced services to our customers have provided a substantial growth in utility investment potential, all the while mindful of maintaining competitive customer rates. So, hopefully, this teaser has incented you to put our upcoming December investor mornings being held here in Toronto and in New York into your calendars. And with that, I'll turn the call over to the operator to open it up for questions from those on the line. Operator?

Thank you. [Operator Instructions] The first question is from Sean Steuart with TD Securities. Please go ahead.

Thanks. Good morning, guys.

Good morning, Sean.

A couple questions to start. Beyond the Peru transmission project that you updated, can you give us any context on other prospective growth that AAGES has on deck, things that you’re considering for that JV?

Yes. Well, I guess, I’ll say that you probably heard I’ll say of some of the things, but if you tuned into the Atlantica earnings call earlier this week, Santiago on behalf of Atlantica outlined a number of growth initiatives, some of which actually touch AAGES as well because they’re more on the development side of things, particularly, there is natural gas transmission platforms that I think AAGES can be helpful in. We’re looking at and working on additional water desalination, happens to be in North Africa. There is a project that would be complementary to a project that -- couple of projects that Atlantica owns right now. Interestingly, water desalination, believe it or not, in the U.S has legs in California. Wind, down in Uruguay is an area of interest. So, I think, Sean, in summary, I guess, we are continuing to look at opportunities that feel pretty similar to the portfolio of projects that are already in Atlantica from an international perspective. And maybe this is a teaser for our investor morning, the intension is to provide a little bit more color into some of the specific in terms where, how much, when at the investor morning. But, I think there is -- I must say, there won’t be any positive or negative surprises. It’s working kind of exactly the way we had hoped, Sean.

Okay. Thanks for that detail. My second question, this claim from Gaia Power, can you talk a little bit about that to the extent that you’re able? And context of the royalty agreements, have any royalties been paid, what context can give us there?

Let me start by I would say with the punch line is from our and our legal team’s perspective, the claim’s completely without merit. So, let’s just start with that. But, a little bit of context Gaia Power was a junior developer who brought the Amherst Island project to us more than a decade ago. And in return, he was entitled to a small royalty interest in the project. And as you know, the project was only commissioned mid this year. And under the terms of royalty agreement, actually -- not royalties, actually owing, technically yet. So, we got to tell you, we were completely surprised at the claim. It’s -- as I said, we’ve looked through it, don't see any merit in it whatsoever, but -- and legal counsel sort of said, well, given the lock of merit in it, if you don't want to put it into your disclosure, that's fine. But, I think our thought was just in the interest of transparency, we threw it in there. So, it’s there. But from our perspective, and as I said, I will end with the punch line is the claim’s without merit.

The next question is from Rupert Merer with National Bank. Please go ahead.

So, looking through your disclosures on development pipeline, you have a few wind projects you’re looking to move to construction sort of 2020, 2021 timeframe. Can you talk about any significant hurdles you may have to get those projects to construction and how many of them do you think will graduate out of that group?

Well, I think, I mean, it's an insightful question that 2020 is shaping up to be I'll say a gold rush year for a wind production. Right now, estimates are somewhere between 12 and 15 gigawatts worth of new production, and not surprising because that is the end of the 100% production tax credit. Given where the energy market is trading that the next year dropped to 80% is obviously material. So, what that means is some of the challenges that sit in front of developers who want to get their projects done, I guess are kind of generally twofold. One is, you've got to lock up the turbines and you have to lock up delivery slots; and second of all, surprisingly, you have to lock up a balance of plant foundation and most importantly crane contractors because you can imagine a crane needed to lift on the cell, on the top of a 120-meter tower is a somewhat complicated and unusual piece of equipment. With respect to the first challenge, we're pleased that we have been able to negotiate arrangements primarily with Vestas to be able to supply the incremental turbine needed and turbine components needed on top of the Safe Harbor turbines that you know we purchased at the end of 2016. And so, I think as we look down the road for all the projects that need to get done, and they're not just -- as you can appreciate, they’re not just on the non-regulated side. We're building 600 megawatts worth of wind within Empire. And so, we've been able to lock up turbine delivery slots. And frankly with respect to the second challenge, we have negotiated and in the process of negotiating agreements with various BOP contractors to secure crane. So, I think we're in pretty good shape for completion. And it's going to be in the neighborhood of about a gigawatt maybe a little bit more of projects in 2020, and that's comprised of the 600 megawatts of wind in the Midwest. And then the other projects that you've seen identified in the MD&A. So, fingers crossed, I think we're taking the steps. And it feels a little weird that we're having this conversation in the fall of almost two years before the deadline. But man, I think if you leave it to the end, you're going to find yourself not in a very good shape. So, anyway, I think I don't -- Rupert if that's the kind of the color you're looking for, but we're on it.

Yes, great. Thank you. As a follow-up to that for David. You talked previously about looking at a cash tax rise in I think 2021, 2022. If you go ahead with this 1 gigawatt of new construction, how far can that push out your horizon to cash taxes?

Well, I think it can push out a fair bit. I think if we did nothing as the horizon's 2021, but we have the ability to be our own tax equity provider in the number of U.S. wind projects. And so, we're reasonably confident that we can continue to keep pushing it out. I mean, I always like to point out. If you would ask me three years ago, what our tax horizon would be, I probably three years ago would have said 2019. And now we've got it out to 2021 and I think we’re confident we can keep pushing it out for a little bit longer.

The next question is from Nelson Ng with RBC Capital Markets. Please go ahead.

Thanks. Just quick clarification on the tax reform impact. I think, David, you mentioned that the net impact would be about 3% to 5% of 2018 EBITDA. But, I think previously, you guys flagged that it would be 2% to 3% of EBITDA. Could you just clarify the tax impact, or was there new agreements reach that kind of pushed the impact a bit higher?

Yes. I do apologize. I guess, I misspoke them. Because the impact that we're experiencing is completely consistent with what we were expecting. So, 3% is definitely kind of what we're seeing and is I think what we previously communicated.

Okay. And that is back end -- that's towards the back end, because it's just been implemented, right, or implemented in Q3 and in October, right?

Yes. That's right. So, the Missouri -- the Missouri rate order came over the summer, we implemented beginning August 30th, and that will continue to roll through our results. But, keep in mind that given all the other utilities that we have, we're always going to be having other rate cases that are going to be coming into the mix as well. And as you said, over 90% of our customers, tax reform is in the rear view mirror.

Okay, got it. My second question relates to the ATN3. So, I think you alluded to how there's already project level debt and construction already started, but it was halted. Did I get that right?

Yes. I haven't heard the question mark yet. But you are correct, yes, Nelson, but yes.

So, can you talk about how, like what the timing was and what the timing will be in terms of when did construction start, when did it halt? When do you think to get going again? And I think the completion date was for 2020 or 2021?

So, that project got going -- I'm sure it was in development before this, but the wheels fell off the wagon after construction has started. And I believe the construction was halted, I want to say in late 2015 or early 2016, it's probably in 2016. It was before we got involved in it. And it rose, not surprisingly because with the financial troubles of Abengoa, certain covenants were being maintained with respect to the project level debt, which has been sourced locally and in Peru, and consequently, project construction halted. The majority and I mean like 90% of the supplies and equipment have been procured and have been warehoused. And so, -- but two things were required in order for construction to resume. And I guess we’re pleased that one of those is in the rearview mirror. And that is an agreement with the project lenders as to what needs to get done to rectify the defaults under the project debt and allow the project to continue. And the second one which is now in front of us is management of the process of updating the concession agreement pursuant to which revenue is earned from the project. You can imagine that the dates that were originally set in the concession agreement aren’t going to be met. Now, to be specific -- to specifically response to your question, I would think that while we don't really have a clear idea of how long this administrative process is going to take with the Peruvian government, I think probably late next year's seeing construction resume and it's probably got 24 months in front of it or so. So, it feels like 2022, that project would -- that $0.25 billion would have been invested. I don’t know if that was kind of the color you were looking for.

Yes. That’s clear. Thanks, Ian.

The next question is from David Quezada with Raymond James. Please go ahead.

So, my first question here is just on the international opportunity here. I mean, there is some commentary in MD&A that suggests that once the project reaches COD, you’ll decide whether or not it would be held by Algonquin offer for sell to Atlantica or remain in AAGES. Just wondering if could remind us what the circumstances would be where a project would be optimal to stay in AAGES, so that whatever happened, I know there is some interplay between cash earnings and EPS between Algonquin and Atlantica, but just on the AAGES side, just to clarify their.

Sure. Maybe give a little bit of color and a little bit of context. A project that fits into Algonquin proper, obviously needs to be optimally financed using the on balance sheet finance structure that Algonquin has and which is consistent with and a contributor to our investment grade triple B flat credit metrics. Clearly one of the distinction characteristics of Atlantica and frankly AAGES would fall into the same category is that, they are users of maybe arguably skilled at project financing, project level financing, which is generally secured solely by that asset. I think that's an important flexibility that our investment at Atlantica was -- we contemplated when we made that original investment. And so, part of the decision as to where the project will end up is whether the project -- what is the optimal financing and capital structure for that project. You can imagine a project that happened to have non-U.S. dollar denomination probably is a strong candidate for project level financing source locally in the jurisdiction which that project exists and consequently would probably be a candidate to be held in Atlantica or potentially continue to be held in AAGES. But, I would say, that’s the lower probability location because Atlantica is the most likely project finance locale. And if the project happens to be optimally financed using our on-balance sheet bond structure, then that project would show up in Algonquin. David, I don't I know if I’ve confused things or clarified them for you.

No. That’s really good color. Thank you. And then, just my other question here. There was some commentary with the Atlantica release on potential U.S. wind projects that Algonquin would go forward on with them. Just wondering, if there's any high level context you can provide on that process, timelines and funding et cetera.

Sure. What a great segue from my previous answer. As we look at as optimally financing projects globally using project financing, well that thesis also applies to North America. And I think what Santiago is making reference to is, are there projects that we could partner up with Atlantica in some way to be able to bring the project financing to bear in North America for North American wind projects. Atlantica clearly obviously has the North American presence, owning the largest solar and storage project in the U.S., down in California, Arizona actually. And so, we've been trying to make maximal use of synergies between Atlantica and ourselves as we think about investing in North America wind and solar projects. And so, what Santiago was alluding to is there's a very specific project which is actively under discussions. It would be included in the projects that Rupert was speaking to of 2020 construction projects. And so, we think it would be -- it's going to be great. And I would offer up again as a teaser for our Investor Day, come to Toronto or come to New York and get more about it. David, I don't know if that's helpful.

Great. That sounds good. I'll see you guys there.

Okay, great. I appreciate it.

The next question is from Ben Pham which BMO Capital Markets. Please go ahead.

Okay, thanks. On the Atlantic 16.5% pending transaction, is Algonquin surprised it's taking this long to close, when you look at the first tranche and the timing?

Yes. I would say, it is. The good news is, I think we're just about out of the tunnel. Well, actually let me say, Abengoa is just about out of the tunnel. We've been waiting by the end of the tunnel for them to emerge. But, maybe give a little bit of color behind it. There are a number of regulatory approvals that are required for Abengoa to sell, not so much for us to buy, but Abengoa to sell. And the two primary approvals relate to consent of the tax equity provider for the U.S. solar projects and the Department of Energy in the U.S., given its involvement in the development and funding of the Solana and Mojave solar projects that I spoke of earlier. My understanding is that while -- and we're sort of spectators to it that the hurdles have largely been gotten over and consequently we're expecting closing this quarter. It has taken longer than we had hoped. But, I guess I don't say not surprisingly dealing with the government entity, like the Department of Energy, maybe it just took longer. And so, as I said, spectators to the sport, I guess we're glad that the game is coming to an end, Ben.

Okay. That's good to hear. And can I ask on the industry theme, we're seeing some of your peers probably levering up too much to your last cycle, on M&A, so now it’s all selling assets and whatnot. And you guys kind of avoided that and didn’t lever up and the balance sheet is in good shape. But how do you guys think about recycling now with what water utilities paying massive premiums for gas? And then, you got some wind assets in Canada trading 12, 15 times EBITDA. How do you guys think about that in a moment?

Well, in my mind, in some respect, there's I'll say two separate opportunity sets. Clearly -- and I don't say we're pleased because it makes it sound like it was luck of the draw that we're pleased that we managed our balance sheet, maybe arguably our M&A aspirations in a sufficiently disciplined manner, so as not to get ourselves in the situation where our credit metrics were stretched. And so, we didn't -- we don't find ourselves in the situation having to sell assets. I think, there is an opportunity that can be created by that. And as we think about some of the utilities that might come for sale, certainly we want to keep our eye on those, though I will -- always against the backdrop. And you've heard me say this, which is, we only want to do stuff which is accretive and when I say accretive, it’s accretive on a bunch of dimensions, obviously EPS and growth profile but one of them is credit metrics. And so, I don't think you would ever see this organization say, oh, that acquisition is so accretive that we have to threaten a potential downgrade of our credit metrics in order to achieve it. So, I’d just say, I don’t think it’s by luck but I think there is an opportunity set coming as a result of some of that. Your second question in terms of should we be recycling some of our capital into, by selling into some of the strengths. So, clearly, the strengths that you're seeing in selling the wind and perhaps and more notably, I think the hydro generation, yes, we look at it all the time. And I think the question one needs to ask -- first of all, we’re never in love with an asset, everything is for sale always. The question we ask ourselves is, are we buyers, holders or sellers of anything in the portfolio. And while certainly some of the prices on -- when you watch people’s gasket sold, that would definitely not induce us to be buyers of that. And the question is, do we want to sell into that strength? And well, nothing comes to mind right now. And I think when you look at our results, part of the benefit which has made this organization been able to post stable results, is the diversification of our portfolio. And well, yes, we could -- we might be able to sell down some of the assets, clearly one of the costs to that is the breadth of diversification. But, I think trust has been that -- and maybe the answer is, we’re never in love with an asset, and we're always evaluating whether the strength in a particular market has caused us to be a seller into it or buyer into it and right now certainly caused us to sit on the sidelines for some opportunities. But it has quite pushed us to take advantage of selling some of these things. I don’t know if that’s helpful, Ben.

Got it. It is seems like it’s great sellers market right now, despite rising interest rates. So, just wanted to get to get a good pulse on that from you guys. Thanks a lot for comments.

Yes.

The next question is from Robert Hope with Scotiabank. Please go ahead.

One of the follow-up on Ben's question, and actually just touch on the potential for Atlantica to co-invest in the U.S. wind project with you. I guess, more holistically, when you do look at your U.S. non-regulated generation assets. Down the line could we see further involvement in Atlantica and ultimately a separation between the utility and the generation business?

Well, it’s an interesting thesis. Right now, we’ve only taken it to the point where if the optimal capital structure for a particular project involves project debt, then Atlantica might be a great partner for us, given their expertise and use of that financing vehicle. Whether we would transfer everything that right now, clearly we think there are assets that are optimally held within on the Algonquin balance sheet. If you’re asking a question, is that a possibility? Yes, it would be. I think though -- let’s caution a little bit, which is you know that part of our thesis is we don't want to consolidated Atlantica onto our books. And so, I think that probably gives us a natural limitation as to how big our interest would be. Maybe that is a follow-on to Ben's question, which is, if you can sell an asset into someone who which you already hold an interest, maybe that’s a great way of heating your cake and having it too in that going forward. So, right now, I don’t think -- I wouldn’t want to attribute the thought of participating with Atlantica in that wind project that Santiago disclosed as a harbinger of a more strategic realignment of the organization. Back to Ben's question, we like the diversification, I think it’s providing value for our -- for all of our stakeholders. And so, right now, it was really a thesis about how to optimally participate in that market.

Thank you for that clarity. And then, just moving north of the border, just in terms of putting more capital to work in Canadian wind, when do you think you could or do you think you will consolidate the rest of Empire, and when could we see shovels in the ground for a Blue Trail.

Okay. So, while Amherst is done, I think so given some clarity on that would be 2019, I think it's probably a reasonable timeframe, we’re just wrapping up kind of final cleanup of roads and stuff like that. So, that’s immanent. In terms of Blue Hill, I think construction right now is likely to start not next year but probably the year after. And frankly, what’s delaying it is certainly I’ll say nothing on our side. You can imagine there is natural investment that needs to be made by SaskPower to be able to accommodate that. And so, I think this is just, I'll say that the natural delay in utility investment for the interconnection. So, I think you know probably a ‘20, ‘21 start, and 12 months from that, maybe ‘18, it'll be done. Certainly what you will hear about it at our investor day and it sounds like I keep plugging it is, we'll give you a little bit more color for that asset. And obviously, it will be a contributor, we spend time on what the five year planning horizon looks like for us from an earnings and an EBITDA growth perspective. It will be factored into that five-year horizon, we'll give you a little bit more color on the specific timing. I don’t know if that's helpful Rob to give you how things are unfolding.

No. That's great. Thank you.

I appreciate it. Thanks Rob.

The next question is from Mark Jarvi with CIBC. Please go ahead.

Yes. Good morning. I just want to go back to the comment on Atlantica, maybe investing in that 200 megawatt wind project. Why wouldn't that be done in AAGES and then drop down into Atlantica, like why wouldn’t you participate earlier on?

Oh, sorry. It is Mark. I think the step just got missed. Clearly that is the thesis. I think obviously Santiago is looking at it as -- when he was describing it, that's kind of a COD involvement. So, yes, to what you described. There's been no change in thesis that AAGES would be developing, and maybe then getting right back to -- and I don’t know if it was Nelson's question or perhaps Rupert’s, which is there is an opportunity for a project that AAGES finished off to be jointly held by Algonquin and Atlantica post this COD. So maybe it's not binary that it ends up in Atlantica or ends up in Algonquin. But, yes, Mark, you are correct. It flows through AAGES.

All right, thanks for clarifying. And then, I just wanted to go in terms of sort of the counterbalancing, you guys have seen where shrink in utilities has offset some of the weakness in renewables beyond weather patterns. With decoupling that comes in, in Missouri, how do you guys see that evolving in terms of kind of that counterbalance going forward.

Well, it's an interesting question, and arguably they're both God's will. And the question is if God's will correlated there, i.e. is God's will that influenced the higher cooling degree days in Missouri, somehow correlated with the lower winds that we suffered in Texas as an example. I don't know if it is or isn't. If clearly there -- if they were correlated, then you’re right, you probably wouldn't want decoupling. I don't think they are. And I think just in general decoupling lowers the riskiness of one of the, I’ll call it, assets in our portfolio. And if you use your portfolio theory, reducing the risk unless you had some perfectly negatively correlated factors in your portfolio, you've actually improved the portfolio by reducing the risk of any individual security there. So, I don't like to explain why weather influenced the outcome of our utilities. Our customers don't like to pay higher bills just because it happened to be hotter in the summer. So, it's all good, frankly, from everybody's perspective decoupling. And so, we are pleased that decoupling came in. But, as I thought about it a little bit more, I don't think it -- I don't think it negatively impacts the overall I'll call it risk of the portfolio. It's an interesting proposition, but I have spent some time thinking about it. And it really does come down to the correlation of those risks.

Fair enough, I’ll leave it there. Thanks.

All right. Thanks, Mark.

This concludes the question-and-answer session. I'd now like to turn the conference back over to the presenters for any closing remarks.

Thanks very much operator. I appreciate everyone taking time to join us on the call today. Hopefully, we'll see lots of familiar faces and maybe some new ones at our Investor Days in early December. So, check out our website to join up. And with that, I'll turn things over to Alison for our disclaimer.

Thank you, Ian. Our discussion during this call includes certain forward-looking information that is based on certain assumptions and is subject to risks and uncertainties that could cause actual results to differ materially from historical results or results anticipated by the forward-looking information. Forward-looking information provided during this call speaks only as of the date of this call, and is based on the plans, believes, estimate, projections, expectations, opinion and assumption of management as of today's date. There can be no assurance that forward-looking information will prove to be accurate, and you should not place undue reliance on forward-looking information. We disclaim any obligation to update any forward-looking information or to explain any material difference between subsequent actual events and such forward-looking information except as required by applicable law. In addition, during the course of this call, we may have referred to certain non GAAP financial measures including but not limited to adjusted net earnings, adjusted EBITDA, adjusted funds from operations and adjusted earnings per share. There is no standardized measure of such non-GAAP financial measures, and consequently APUC's method of calculating these measures may differ from methods used by other companies, and therefore they may not be comparable to similar measures presented by other companies. For more information about both forward-looking information and non-GAAP financial measures, including a reconciliation of the non-GAAP measures to the corresponding GAAP measures, please refer to our most recent MD&A files on SEDAR in Canada or EDGAR in the United States and available on our website. Thank you.

This concludes today's conference call. You may disconnect your lines. Thank you for participating and have a pleasant day.