Thank you for standing by. This is the conference operator. Welcome to the Algonquin Power & Utilities Corp. 2020 Third Quarter Earnings 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.

Thank you. Good morning, everyone, and thanks for joining us this morning for our 2020 third quarter earnings conference call. My name is Amelia Tsang and I'm the Vice President of Investor Relations of Algonquin Power & Utilities Corp. Presenting on the call today are Arun Banskota, our President and Chief Executive Officer; Arthur Kacprzak, our Chief Financial Officer. Also joining us this morning for the question-and-answer for the call will be Jeff Norman, our Chief Development Officer; and Johnny Johnston, our Chief Operating Officer. To accompany our earnings call today, we have a supplemental webcast presentation available on our website, algonquinpowerandutilities.com. Our financial statements and management discussion and analysis are also available on the website as well as on SEDAR and EDGAR. Before continuing the call, we would like to remind you that our discussion during the call will include certain forward-looking information including but not limited to our expectations regarding future earnings and capital expenditures as well as potential future impacts of the COVID-19. We will also refer to certain non-GAAP financial measures, and at the end of this call, I will read a notice regarding both, forward-looking information and non-GAAP financial measures. Please also refer to our most recent MD&A filed on SEDAR and EDGAR and available on our website for additional important information on these items. On our call this morning, Arun will provide an overview of the strategic achievements for Q3 2020, Arthur will follow with the Q3 financial results, and then Arun will conclude with an update on our strategic plans for the business. We’ll then open the lines for questions, and I ask that you restrict your questions to two and then re-queue, if you have any additional questions to allow other opportunity to participate. Before we turn over to Arun to discuss our progress in Q3, we will have Chris Jarratt to make some fare well remarks. Chris?

Great. Thanks, Amelia. Before we start the formal part of the presentation, I'd just like to say a few words all the analysts and investors who are on this call. As previously announced, I will be retiring at the end of this month, and today will be the last time I'll be on these calls. As a co-founder of the organization, I've had the honor of serving employees, investors and customers for the past 32 years. I have to tell you it's been an incredible journey to be part of growing a company from a single room office above a convenience store with a $12 billion asset rich company, which we are today.

Thank you, Chris, and good morning to those who've been able to join us on the call and online. Our diversified business model delivered stable results, and I'm pleased that we had a strong third quarter among the disruptions due to the global pandemic, reporting Q3 adjusted net earnings per share of $0.15 compared with $0.14 per share last year. Looking at our regulated services group, we are a business providing mission-critical energy and water services to our customers. We continue to perform well, both from a financial and operational standpoint as we navigate through the impacts of COVID-19. Given the resiliency of our business model, the Company has been able to provide uninterrupted utility services since the onset of the pandemic without compromising on the safety and quality of those services. As expected, given the changing consumes and patterns of our customers, we have seen some moderate decreases in customer demand across some of our utilities, impacting our third quarter adjusted net EPS by $0.01 and bringing in the year-to-date effect of COVID to $0.02 per share. We have been able to offset the decline in operating profit by implementing cost containment strategies that year-to-date have provided $18 million of savings, already above the $50 million we had committed for the year.

Thank you, Arun, and good morning, everyone. In the third quarter of 2020, our business operations performed well amid the COVID-19 pandemic.

Thanks, Arthur. Before we close out our prepared comments this morning, I want to give an update on our growth initiatives. We'll then open the lines for the question-and-answer period. We remain committed to our strong track record of growth with many different levers at our disposal. We remain track for our five-year $9.2 billion capital plan through the end of 2024. And in fact, plan to exceed that with our newly announced accretive investments in ESA. In our regulated services group, we have a successful track record of acquiring utilities and have a very specialized skill set of integrating them into the Algonquin family. We recently completed two acquisitions, BELCO and ESA. And the acquisition of Newer American Water is expected to close in 2021. In addition, we have smaller organic tuck-in opportunities in existing areas of our operations that contribute to our customer growth each year. All of these acquisitions over the years have allowed us to reach our latest milestone of 1 million customer connections. Another lever of growth, as we transition to low-carbon energy is our greening of fleet initiatives, including our customer savings plan, where construction in the Midwest continues to be underway, and we will look for similar opportunities in Bermuda. In addition, we expect to realize strong rate base growth from our organic investments as we improve the safety and reliability of our infrastructure. In our renewable energy group, we also have many growth levers, including our ability to execute on the Company's largest construction program in our history and I wanted to provide you with a couple of project updates. Our major renewable energy construction projects are considered to be essential infrastructure in the jurisdictions in which they are located. And therefore, construction has proceeded throughout the COVID-19 pandemic. At the end…

Thank you. We will now begin the question-and-answer session. Our first question comes from Sean Stewart of TD Securities.

A couple of questions. Arun, I'm wondering if you can discuss the legislation in New York in more detail. And how this might affect the thinking around the proposed acquisition of New York American Water?

So, the legislation has recently come out, and we're obviously digging into a lot of details. At first glance, our conclusion is that it's primarily end towards the emergency response and storm response from the utilities in the state. There's also provisions for increased fines and penalties that the commission can impose on the regulated utilities. There's also a provision in the bill for a study on municipalization. And look, from our perspective, we welcome this kind of public debate and discussion. At the end of the day, we believe we are best positioned to provide those essential water services to the customers of New York American Water, and we are looking forward to engaging with all of the stakeholders as we go through this process. We still remain confident that at the end of the day, we will be able to close this transaction in 2021, and we remain very engaged with the commission and other stakeholders in the state currently.

Okay. Second question is for Arthur. The tax credit tailwind this quarter related to the PTCs and ITCs. Can you give us a sense of which projects were wrapped up in that number? And I guess, just trying to gauge how we should think about that line item going forward, maybe Q4 and into early next year as well?

Yes, sure. So maybe it might be useful to provide a little bit of context on how we think about sub-monetization of our renewable energy project, and we mentioned some of this back in 2019 Investor Day. But you can think about sub-monetization really coming as a complement to exercise maximum value out of our projects as a complement of the tax equity. So if you think about it, on our wind projects, for example, the wind projects are placed in service, as you know, not all at once, but replacement service sequentially. But tax equity only funds whenever -- all the projects have been fully commissioned. So there's typically about a couple of months lag between when the first turbine gets commissioned and starts generating tax credits to one we actually could get tax equity funded. So that's a perfect opportunity for us to be able to use some of our internal tax appetite and actually and monetize some of those tax credits. The other places that we use self monetization is maybe or projects where tax equity may not be the most efficient choice to use. There's certainly a cost benefit of arranging tax equity. So again, as we look at maybe some smaller projects or projects where maybe we see the cost of tax equity being a little bit higher we will look to potentially self monetize. So it'd be basically responsive to your question, in terms of the projects, it's a little bit of all of them, to say that we're commissioning this year because if you think about the wind projects, I mean, we are commissioning in total about 1.4 gigawatts of renewables. So there's a lot of opportunity to monetize PTCs. But we also have a couple of solar projects that were monetized this year as well.

Our next question comes from Nelson Ng of RBC Capital Markets. Please go ahead.

My first question relates to the Chilean Water acquisition. Will you be -- this question is, will you be doing anything difference at the Company in terms of -- like are there any capital projects that the Company didn't pursue that you're now looking to revisit? And can you just comment on the drought situation in Chile and how that opens up any potential opportunities? And finally, how all that translates to your expected rate base growth for that investment?

Sure. Nelson. So look, primarily, we remain on North America Energy and Water companies, right? So when this transaction, this opportunity became available, we really looked long and hired because there's a lot of things we really like about the transaction. Water utilities are not easy to come by, a significant number of customer connections. We did a lot of analysis around country risk. Chile as very, very solid country risk that is very low country risk, obviously, it has a strong and stable regulatory environment. And finally, the transaction price was very compelling. So we are confident in our ability to acquire and integrate utilities. And that, we believe, is one of our special skill set, and that's a process we're going through right now in terms of integrating ESA into our overall mix and operational excellence. In terms of how that affects our capital plan, we remain committed to our $9.2 billion five-year capital investment plan, and ESA would, in fact, be an addition on top of that $9.2 billion plan.

Okay. And then this might be a preview to the Investor Day. But in terms of -- on your renewable development side in terms of your development pipeline, can you just give an update in terms of how much PTC qualified wind turbines and ITC qualified solar equipment you have in terms of just, I guess, potential opportunities to fund future projects?

Yes. Hi, Nelson, it's Jeff. And we have been very active, as you know, for years in terms of identifying and securing PTC qualified equipment. Going back to 2016 when we secured about $56 million worth of equipment to fund out the 100% PTC program that we're now seeing constructive, we have transferred a lot of that effort in last year and this year in the transformer process, and we are in the process of securing safe harbor for all of our five-year pipeline between what we've done in the past and what we have -- we'll be doing before year-end.

Okay. And what's your thoughts on like any potential extension of tax credits from a potential Biden government? And does that help or hurt what you might potentially have already secured?

Yes. I think it's too soon to tell what the Biden government is going to do, although clearly should be good for renewables in one way or another. The benefit of using transformers as a big chunk of our qualification is those transformers will be used no matter what, whether we use them for qualification or whether we just use them as a critical component of the projects that we're going to be building. So, we see lots of upside, but no downside.

Our next question comes from David Quezada of Raymond James. Please go ahead.

My first question here, just wondering if you could provide us an update on where you are with the update or the appeal of the rate order in Missouri; just any recent thoughts there? And maybe if you could mention, if you think you have the time now to go through with an appeal before you go back in for rates in Missouri?

Yes. Thank you, David. So as you know, one of the things we have appealed is against the equity thickness that was given to us. I mean, we believe that we have a strong case for a larger equity thickness, and we have appealed that decision. That obviously is going through the process, and we will obviously look at where that stands in terms of timing with our next rate case, which will probably be sometime in 2021 in Missouri.

Okay. Great, thank you for that. And then maybe just another question on cost savings. You've done quite well and it looks like you're on pace to materially exceed your target is there, anything particular that drove that, any bucket that you could point to?

Yes. Maybe I'll start off with this one, and I'll let John add because his team has been doing all the hard work with respect to finding all the cost savings. But I mean, if you think about the cost savings, we've saved about $18 million so far this year, probably looking to save somewhere between another 5 and 10 next year. We kind of think about it as broken down into maybe three buckets. One, our expenses that basically are naturally would have been saved anyway, think about lower travel expenses and so forth. The other one is maybe a bit of deferrals, such as holding positions open and so forth. And the last bucket is really taking a hard look and really trying to find efficiencies, whether looking at our procurement processes and looking at where we deploy capital, et cetera. So, it's really those three buckets that those cost savings come from.

John, you want to add some color?

Yes, thank you David. In some ways, not a huge amount more to add other than maybe I think was getting visibility of the challenges that we had with weather in the first quarter, we were already sort of mobilizing how we could counteract that through the rest of the year. And so I think we've got an early start as COVID started to kick in, really just increased the focus across the team of making sure that we didn't leave any stone unturned for the rest of the year? And I guess we can see the results through that. But I think after you covered off the really the buckets of where the savings are coming from pretty well.

Our next question comes from Julien Dumoulin-Smith of Bank of America. Please go ahead.

And again, congrats, Chris. Thanks for the time and opportunity. I just wanted to talk to you guys about growth trajectory and thoughts around it. Obviously, hearing you guys talk very confidently about the CapEx outlook. How does that translate back to the 9% to 11% growth that we've talked about off a 2019 basis, $0.62? How are you thinking about that CapEx relative to the earnings trajectory that you guys had last year? Because it sounds like everything is reaffirming the trajectory despite some challenges here. I just want to understand how you're thinking about that and then potentially even more, as you've alluded to it and I apologize, I know you have an Analyst Day around the corner here, but just trying to get a little bit perhaps of a preview as you think about the earnings implications, too.

Yes, Julien, yes, but I was hoping you'd ask me that question during Investor Day, but let me give you a preview in any case. Look, I mean, there were onetime downsides we faced this year like COVID and weather, especially COVID totally not anticipated. And on BELCO, there was really a statutory requirement to close this by March 1, and that was really part of our assumption. And so the delay certainly impacted the financials. However, what we believe is what we provided to the market was a five-year 9% to 11% CAGR growth, and we remain confident that we'll be -- we're going to be able to bounce back in 2021. And again, I look forward to providing a lot more details during the Investor Day.

Absolutely. If I can follow-up on that, perhaps a little bit nearer term. As you think about that trajectory, the 9% to 11%, not just in the 2021, should we still think about being able to achieve that trajectory of the 19 base in '21 obviously, there's a lot of moving factors in '20, you alluded to a second ago, including some new found cost savings in the back half of the year here. So just curious on how the sustainability of those efforts into '21, and ultimately, if a good proxy for now should still be the implied CAGR for '21 as far as guidance goes?

For now, Julian, I would say, I would still stay with that analysis of that 9% to 11% CAGR growth. Obviously, like you alluded, a lot of different moving parts in cost savings. We also acquired ESA, which is not part of that five-year plan. And with all of that, we believe we're going to be getting back on track in 2021. But again, those are the -- all of the dirty details we look forward to providing you during Investor Day.

Got it. So it sounds like given some of the incremental points, you're saying perhaps at least that.

Within that range is what I would say, Julien.

Our next question comes from Rob Hope of Scotiabank. Please go ahead.

Maybe just to start on kind of your international strategy. It looks like you may -- you have now purchased an option to buy the rest of Aegis. How are you thinking about some of the structures, you have in the organization to facilitate this international growth? We've seen you do some potential international renewables on your own balance sheet. ESSAL was on your own balance sheet. How does Atlantica and Aegis kind of fit into the structure currently?

Sure. Great question. Thanks, Rob. So by and enlarge, I mean, we plan to do all regulated utilities and North American business through Algonquin, right. We're very happy with our investment in Atlantica, very strong long-term assets with weighted average mine life of 18 years. And so we like the long-term nature of that -- those infrastructures. And so when it comes to international non-regulated assets, we really look at it on a case-by-case basis as to whether it makes more sense for Algonquin to go after that and operate it versus Atlantica. So it really becomes a case-by-case decision. By and large, we believe that if it's anything outside of North America and non-regulated that Atlantica may be in a good position to personas, but not absolutely. I don't know you see a clear answer or not. But there's an absolute formula, but other than that all North American and regulated business will be under the hospices of Algonquin.

All right. Perfect. And then just circling back on kind of the original tax question, how should we think about those $15 million of incremental tax benefits? Will those be realized in Q4? And then are you, in essence, kind of realizing future tax savings? So in essence, the 2020 cash or '20 tax guidance that you gave at your Investor Day it looks like you'll outperform that, but potentially at the expense of future tax expenses?

Yes. Sure. So maybe take that question, of course, the answer to the first question is yes. I mean, the $50 million is going to apply to projects that will be placed in service this year. That will be or have been placed in service. This year, certainly, I mean, in terms of what was there where our, call it, shifting tax, I would say, no. I mean certainly the year we monetize some of the assets, you get a bigger shift. But in essence, it is tax -- it is true tax savings for us. So on equivalent basis, it's not like we're shifting our tax liability down to future years. That was your question, I'm not sure if I followed it correctly.

Our next question comes from Rupert Merer of National Bank. Please go ahead.

Congratulations, Chris, on your retirement and success at Algonquin.

Great. Thanks, Rupert.

Maybe if I could start with a -- just a follow-up on Aegis. How should we think about your partnership with Abengoa going forward? And are there any changes to the ownership in Sugar Creek now that it's completed? I believe that it was acquired by Aegis.

Yes, sure, Rupert. Look, it's pretty public knowledge that Abengoa has been a challenging partner, right? I mean, the whole market knows the restructuring and other challenges that they are going through, so consequently, Aegis has been a challenging vehicle for us. But despite that, there are a series of development projects that Aegis has under its umbrella, including a pipeline of solar development, greenfield development projects in Spain. The last year, pay a 20-megawatt solar project in Colombia that's under construction with coming into commercial operations in Q1. And there's other projects in Latin America that that they are following. I will be the first to admit that with Abengoa as our partner, it has not been the most effective vehicle for us.

So if you do buy out Abengoa's interest in Aegis, what does the just -- what could it look like in the future? And what are the implications on some of the other projects that you have in development in Aegis?

I think we will be turning Aegis much more so into international development pipeline. We have a very, very strong development team that covers regulated and everything in North America. Aegis was always supposed to be that vehicle. And again, we will be the first to admit that it has not been extremely effective on that front, but we would look to reposition it, strengthen it, and create a much more robust pipeline of development projects, similar to what we have in North America.

Based on your earlier comments about the non-regulated business and assets in North America, would we anticipate that development projects images will ultimately be held at the Algonquin level?

Aegis is a development vehicle, right? Where those development projects are actually held and operated is choice that we have, whether that be with Algonquin, whether that be with Atlantica. But again, by enlarge, our view is that everything in North America and everything regulated will be owned and operated by Algonquin. And the question is more around international assets. I don't know, Jeff, do you want to add anything to that?

I think maybe the only other thing, Rupert, I might add is you had asked about the share Creek option and like a number of our construction projects, we maintain an option of BELCO maintains an option to buy out the remaining 50%, and we do fully anticipate now that we've completed construction on that project that we will be acquiring 100% ownership within Algonquin.

Great. And then just quickly on the CSP wind farms. You've got some progressing to CMD quite soon. Can you remind us what the impact will be on your reported results? When those hit COD and what the impact of plant and service accounting may be?

Much of that should be coming online by the end of this year. With COVID-19, we have certainly been challenged by with our global supply chain issues. But despite that, we remain confident that there are not going to be any material delays. So some of the turbines that experienced delays in getting to the U.S. and to the project side, we remain confident that we're going to be able to get all of them online in Q1 of next year.

Our next question comes from Mark Jarvi of CIBC Capital Markets. Please go ahead.

And happy Retirement, Chris. Just following up on Rupert's question. Previously, I think, was to file sometime around year-end to try to get recovery of the investments for the wind in the rate base at Empire for midyear. Is that still the plan? Or just maybe just go back to his question around client services accounting. What is the regulatory plan to take a recovery? And then maybe, Arthur, do you guys start occurring HLBV income early in the year once they're in service?

Sure. Mark, I'm going to start and maybe turn it over to Johnny for more color on this one. So as you know, we elected for PSA, plant in service accounting, which does give us some more flexibility in terms of exactly when we have to go back to a rig for a rate case in Missouri. And ESA gives us the ability to, in fact, put it on our rate base as plants come into service. So with that, Johnny, do you want to add more color to that?

Yes. So as the plants go live, we're able effectively true-up at the next rate case, 85% of the depreciation from the dates that they go into service. So I think as you've heard, looking to file our next rate case next -- early next year once the plants are operational. And so, we'll see them sort of fully represented in rates as they go in service in 2022.

So, there will be some regulatory lag in recovery a little bit on earnings.

So 85% of it, effectively, we're able to track as soon as they go into service, I'd say the majority of the lag is picked up. I guess, the new rates will ultimately be effective in 2022, but we'll be able to have a regulatory account to true-up post that rate case.

And is there any comment on-site contributions?

We'll be able to start recognizing it as they are out our balance sheet.

Okay. And then now with BELCO closed, and maybe you'll give us a bit more of a fulsome update at the Investor Day, but is there anything you guys can share in terms of implementation of the IRP and time line for sort of hit the ground running in terms of incremental investments and moving to grow the rate base at BELCO. Is it 2021, you'll start to see incremental investments or is it a little bit off from that?

Yes. Rupert, I, thanks for that question. As you know, we just closed the transaction. So with COVID-19, one of the impacts has been that the level of engagement was not as robust as we would have hoped. In fact, Johnny and some of our other folks just came back from Bermuda. We're restarting that conversation. Obviously, the economy of Bermuda would like to see investments at the earlier, the better. We have proposed some greening the fleet initiatives. We're excited about that, given a very high cost of electricity on the island as well as the fact that much of it is generated with a diesel engine. So we do see a lot of scope for bringing our fleet initiatives. We will continue those interactions with the government, and hopefully, we'll be able to structure something in the 2021 time frame.

Our next question comes from Ben Pham of BMO. Please go ahead.

Can you provide a bit more context on Granite Bay? And how much you spent on it so far that you plan to recover?

Sure. So Granite Bay, just to give you some context, it was a pipeline with LNG storage facility, and we went to quite a great lens in developing that facility. But at some point, there became pipeline capacity available that was not there before. So obviously, we're looking at -- we want to do the make the best investment for our -- that's right for our customers as well. So we have basically formed up that long-term pipeline capacity with the Granite Bridge project as it original stood is not going to be the same kind of a project. Although we do think that there's going to be quite a bit of investments required to strengthen some of the reliability of the system, pipelines, things of the sort. So we do believe that there's still room for some investment, but it's not going to be the same scope as before. I don't know, if John or Jeff, want to add anything to that.

Yes, Arun, I would just add that I think you've done a great job of summarizing what we did and how it turned out that creating that option, which was the option of being able to get additional supply to meet our customers' growing needs through the pipeline of the LNG ultimately gave us as a very strong negotiating position to benefit the customers. And so the investment that was made, we believe, created value, and we're working with the physicians to and are getting positive feedback that they see that value and the creation that was there. In addition to, we will need to put in resiliency investment to facilitate the incremental capacity from the pipe.

Okay. Can I go back to the -- some of the tax questions, and I hope I don't compete myself more than I should. Just I wanted to confirm is tax crew, is that related to your past guidance around becoming a tax acute investor yourself because your corporate tax rate is going up? Or is this basically accruing ahead really the share of the tax equity investors attributes ahead of time before they come in.

Yes, it is us becoming our own tax equity investor. We are not currently a cash taxpayer, but let do ourselves being a cash taxpayer a few years out. So to some extent, it is taking some of those tax attributes that will be used. We could see ourselves using them over the next two to three years.

Okay. That makes sense. And I also want to confirm when you -- you're monetizing that yourself becoming an investor. Is that -- was that always in your CapEx plan? And financing outlook? Or do you have to tweak that in the future?

I would say we do it, call it, opportunistically, again to optimize around the tax equity investments that are there. So to some extent, yes, it's thus form a portion of our plan. But again, it's -- we've kind of think about it opportunistically because to some extent, we don't know what to call it, going back to the how long the lag is going to be between the first turbine it's commissioned and when ultimately, tax equity funds. And so that is a little bit of fluid, but we certainly use that as a strategic asset.

Okay. And maybe the round up ad as a bit here. When you first introduced this a bit more aggressively a few years back, you mentioned that your tax rate could be 5% or so. And in you moved up to 10% in the last Investor Day. So is this accrual of tax credits? Are you going back to that 5% two years ago or is that 10% still a reasonable number to use going forward?

Yes. I think certainly, in the near-term year, where you end up self-monetizing attributes that does push our tax rate down to the extent that if you look at on an overall run rate tax rate, call it, if we weren't -- didn't self-monetize anything in the next year, I think the guidance that we've given at an Investor Day still holds.

Our next question comes from Richard Sunderland of JP Morgan. Please go ahead.

Maybe starting off first with the Chile acquisition, curious to get some color on the environmental issues that the assets have had and maybe risks and opportunities around that specifically under your ownership going forward?

Sure. Richard. So obviously, during our due diligence, those are some of the things that we looked at very carefully. I mean also no incident also some of the rain water spills that that have occurred. And our due diligence was really around our is, there something fundamentally broken? Are these onetime issues that are fixable. And in the end, we made a determination that by strengthening that culture of safety, security, reliability within ESA that we would be able to get the Company back on track and make sure that we did not incur those kinds of incidents in the future. I mean clearly, right, and what has happened in the past does -- has impacted ESA in terms of its reputation and the view of the community around ESA. And so we clearly have our work cut out but we feel confident that with our culture of operational excellence that we are going to be able to get that company back on track.

Great. And then you touched on this earlier briefly around kind of the growth outlook. But just thinking about the dividend specifically, any updated thoughts on the dividend policy given the elevated payout ratio this year? You certainly appreciate that there are the one-off impacts to 2020 spoke to, but how to think about that going forward?

Yes. Richard, it's Arthur. So maybe I'll try to take that one. So yes, I mean, your observation, our payout ratio is maybe a bit higher than our U.S. peers and maybe some of our Canadian peers as well. But I would say, kind of keep in mind, there were also one-third IPP business. So we're not a pure utility. I mean in terms of the dividend, that maybe we'll talk a little bit more about that on our Investor Day. But maybe what I'll leave with you with today is that we certainly view the dividend growth as an important part of the total shareholder return that we provide.

Our next question comes from Naji Baydoun of Industrial Alliance Securities. Please go ahead.

Just going back to the cost savings initiatives. Arthur, I appreciate the details you provided on sort of the three different buckets of where those are coming from. How much of that would you say is sort of a recurring or run rate savings that you think you can maintain into next year and beyond?

That's a question. I mean it's certainly probably not zero, but it all depends on kind of what the new normal is. We've certainly have built in some efficiencies. But as I said, there's also maybe a little bit of holding powder type costs. So, it's difficult to see how much of that is going to translate call it into next year. But I mean, I think certainly, it's not zero in terms of the cost savings we've identified that could be sustainable.

Okay. And it might be a bit too early to tell how things will play out. But do you think there are other sort of savings that you're looking at maybe being able to target for next year too?

We're always looking at savings is probably the answer, Naji. I mean that's one of the levers we have. I mean I talked about operational excellence it's all about how can you maximize the output with a given set of inputs and that formula is something we look at all the time, absolutely. And especially this year, given the significant impact on our EPS with BELCO delays and COVID and weather that was something we probably turned over every stone in the Company, but that's something that we look at all the time.

Okay. Okay. And just -- can you just remind us that I think you have another big year coming up next year for rate filings, other than the Empire rate case. Can you just remind us what are some of the other major filings that you expect to complete next year.

Johnny, do you want to take that?

Yes. I mean, there's no doubt that the biggest filings that we've got next year is the Empire rate case, as you're probably aware we're in the middle of our energy North rate case at the moment? And then we've got a couple of other rate case filings that we're looking to do next year, but they're smaller. So things like Illinois gas rate case. So yes, I think you've got the big one. The other big one coming through is our energy North case.

This concludes the question-and-answer session. I would like to turn the conference back over to Mr. Banskota for closing remarks.

Thank you, operator, and thank you, everyone, for taking the time on our call today. With that, please stay on the line for our disclaimer.

Thanks, Arun. Our discussion during this call contains certain forward-looking information. Including, but not limited to, our expectations regarding future earnings, potential future cost savings, future placed in-service dates and potential future impacts of COVID-19. This forward-looking information is based on certain assumptions, including those described in our most recent MD&A filed on SEDAR and EDGAR and available on our website 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, beliefs, estimates, projections, expectations, opinions, assumptions of management as of today's date. There can be no assurance the 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 net earnings per share or adjusted net EPS, adjusted EBITDA, adjusted funds from operations and divisional operating profit. 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 company. For more information about both forward-looking information and non-GAAP financial measures including a reconciliation of non-GAAP measures to the corresponding GAAP measures, please refer to our most recent MD&A filed 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.