FirstEnergy Corp. (FE) CEO Chuck Jones on Q1 2020 – Earnings Call Transcript

FirstEnergy Corp. (NYSE:FE) Q1 2020 Earnings Conference Call April 24, 2020 10:00 AM ET

Corporate Participants

Irene Prezelj – Vice President, Investor Relations

Chuck Jones – President and Chief Executive Officer

Steve Strah – Senior Vice President and Chief Financial Officer

Eileen Mikkelsen – Vice President, Rates and Regulatory Affairs

Conference Call participants

Julien Dumoulin-Smith – Bank of America

Shar Pourreza – Guggenheim Partners

Stephen Byrd – Morgan Stanley

Steve Fleishman – Wolfe Research

Charles Fishman – Morningstar

Michael Lapides – Goldman Sachs

Paul Patterson – Glenrock Associates

Sophie Karp – KeyBanc

Jeremy Tonet – JPMorgan

Durgesh Chopra – Evercore ISI

Andrew Weisel – Scotia Bank

Operator

Greetings! And welcome to the FirstEnergy Corp, First Quarter 2020 Earning Conference Call. At this time all participants are in a listen-only mode. A brief question-and-answer session will follow the formal presentation. [Operator Instructions] As a reminder, this conference is being recorded.

It is now my pleasure to introduce your host, Irene Prezelj, Vice President, Investor Relations for FirstEnergy Corp. Thank you Ms. Prezelj, you may begin.

Irene Prezelj

Thanks Melissa. Welcome to our first quarter earnings call. Today we will make various forward-looking statements regarding revenues, earnings, performance, strategies and prospects. These statements are based on current expectations and are subject to risks and uncertainties. Factors that could cause actual results to differ materially from those indicated by such statements can be found on our Investors section of our Web site under the earnings information link and in our SEC filings.

We will also discuss certain non-GAAP financial measures. Reconciliations between GAAP and non-GAAP financial measures can be found on the FirstEnergy Investor Relations Web site, along with the presentation which supports today’s discussion.

Participants in today’s call include Chuck Jones, President and Chief Executive Officer; and Steve Strah, Senior Vice President and Chief Financial Officer. I will note that we are all virtually participating in this call and we have several other executives on the phone as well that are available to join us for the Q&A session.

Now, I will the call over to Chuck.

Chuck Jones

Thank you, Irene, and good morning everyone. Thanks for joining us.

These are unprecedented times. We hope all of you are listening this morning are safe and healthy. We realize you have numerous questions on how this public health emergency affects FirstEnergy. Our goal today is obviously to review our first quarter earnings, which once again are solid, but also to talk about the journey we’ve been on during the COVID-19 pandemic and the path that we see ahead.

I’ll cover the broader story of our business and why we believe our strategy is built for resiliency during this crisis. I’ll also review the actions we are currently taking to navigate in today’s environment. Overall, I’m confident we’re well positioned to manage through these events.

First, to diversity and scale of our transmission and distribution operations across 65,000 square miles in five states is a fundamental strength for FirstEnergy. We operate critical infrastructure, and that means everything our employees do is considered essential work. But as we continue this important work to maintain our large electric system and provide the energy our customers and communities need. My number one priority is to help keep our employees, their families and our customers safe.

Minimize the risks, we have taken significant steps to quickly adapt to the new circumstances and protect the health of our employees and customers. We successfully transitioned more than 7000 employees to work remotely. That’s more than half of our workforce and it includes moving our call center employees to a work at home environment as well.

For our workforce unable to work remotely, we’ve implemented preventative measures to help keep them safe on the job. We’ve secured protective equipment like surgical masks, and other supplies like thermometer, they’re being used by our operated companies, regulated generation plants and other work groups.

We have also increased cleaning and disinfecting measures, relocated job briefs and reporting locations to sites conducive to social distancing and adjusted work schedules. We have positioned crews so they are working with the same small group of people each day and what we call pods. They’re consistently using the same vehicle and the same equipment to limit exposure. And we are managing our work to minimize potential exposure with the public.

We continue adjusting our work plans and remain flexible to meet the ongoing needs of our workers, minimize the spread of this virus and adopt the current guidance from state and federal health agencies. It takes consistent communication on everyone’s part, focusing on the health and safety of our employees and customers throughout the process.

This pandemic has become a defining moment for our country and our company. What encourages me is knowing that we will emerge from this stronger because we’ve come together to learn how to work smarter, more creatively and more efficiently.

In fact, we’re all very well positioned to manage the impact of the economic slowdown. And we believe our distribution and transmission investments will continue to provide stable and predictable earnings.

As the situation continues to develop, the diversity and scale of our operations gives us the flexibility to shift our investments if needed and continue deploying capital throughout the system. While we’re keeping a close eye on our supply chain, we do not anticipate significant disruptions.

Since the middle of March, we have been looking at the early impact the pandemic is having on usage trends, both from a system wide load perspective and from a sampling of Pennsylvania smart meter data. We have see seen system wide weather adjusted load dropped by almost 6% from mid-March until mid-April, compared to the same timeframe last year.

We’ve also seen increases of more than 6% for Pennsylvania residential customers driven by the stay at home order. We would expect similar increases in residential usage across the rest of our service territory. It’s all of our states are operating under stay at home orders.

All our commercial and industrial customer load is down almost 13% compared to our four year average, from 2016 to 2019. I would remind you that prior to the pandemic we were already seeing reduced industrial sales due to the manufacturing recession. However, our rate structures provide a measure of stability even in tumultuous times. About two thirds of our base distribution revenues come from residential sales, while 28% are from commercial customers and about 7% come from the industrial sector. And about 20% of our total load is on the decoupled rate structure in Ohio.

In addition, a significant portion of our base distribution revenue isn’t directly tied to energy consumption, but is derived from other billing determinants. In fact, about 80% of commercial rates and 90% of industrial are made up of customer and demand charges.

We are pleased that in Maryland, the Public Service Commission proactively issued an order this month authorizing deferral for future recovery of all prudent incremental COVID-19 related cost. The strong regulatory policy demonstrates firm support for our customers and our business. I would like to personally thank Chairman Stanek and the rest of the commissioners in Maryland for their leadership on this important regulatory issue. We can also recover incremental uncollectible expenses through existing writers in Ohio and New Jersey.

Our current regulatory calendar is light through our 2023 planning period. Active items include the distribution base rate case we found in New Jersey in February, seeking to recover increasing costs associated with providing safe and reliable electric service for our customers. Along with recovery of storm costs incurred over the last few years, we expect an ALJ will be assigned to our case soon all by the issuance of a procedural schedule.

In the meantime, the discovery phase of the case has begun for parties to review the date details of our request. We anticipate the litigation scheduled to provide the opportunity to discuss favorable settlement with the parties in the case. We also reached an agreement to transfer JCP&L’s portion of the Yard’s Creek plant to LS power and we expect that transaction to close in the first half of 2021 pending approvals.

In West Virginia, we have a requirement to make an informational filing by December 30 2020 for our Integrated Resource Plan. The IRP updates our plan to provide our West Virginia customers with adequate and reliable generation resources that are reasonably balanced cost and risk.

And finally, we have a commitment to file a rate case for our smallest utility Potomac Edison in Maryland by early 2023.

Moving now to our first quarter results, which marked another quarter of solid execution as a fully regulated company. Yesterday after market closed, we reported GAAP earnings of $0.14 per share, along with operating earnings of $0.66 per share, which is a $0.01 above the midpoint of our guidance range.

Our results were driven by higher transmission margin and lower expenses which helped to offset the impact of mild weather on our distribution revenues. As always, Steve will discuss the drivers in more detail later in the call.

We’re affirming our 2020 earnings guidance of $2.40 per share to $2.60 per share. We are also affirming our expected CAGR of 6% to 8% through 2021 and 5% to 7% extending through 2023 as well as our plan to issue up to a total of $600 million in equity in 2020 to 2023.

In addition, we’re introducing earnings guidance at $0.48 to $0.58 per share for the second quarter of 2020. While the financial markets have been extremely volatile and sometimes illiquid in the past couple of months. FirstEnergy continues to be a low risk stable, predictable utility. We have adequate liquidity of $3.5 billion strong and proven access to the capital markets and a pension plan that’s outperformed in these volatile market conditions due to a slow risk conservative asset allocation. Steve will also cover these three probably in greater detail.

Finally, let me take a moment to discuss our succession planning. I’ve been getting a lot of questions on this. Just because I look old doesn’t mean I feel old. Well, I don’t plan on going anywhere yet. I know many of you have been wondering about our plans for a transition. I can tell you that our Board has been just as thorough and thoughtful on this topic as they are with any other key governance issue. We started planning for my replacements literally right after I became CEO. What started as our typical emergency planning has evolved into robust succession planning discussions.

In 2018, we made several moves that were designed to broaden the experience of some of our key executives. This included placing Steve into the CFO role, bringing Sam Belcher over from FENOC to become President of the Utilities and moving John Taylor out of the Finance organization into a leadership role and distribution operations.

The Board and I are continuing discussions and I would expect you may see additional organizational moves within our leadership team in the coming months. They’re part of what I said will be a thoughtful transition and leadership at FirstEnergy. But having said that, I have made no decision about my own retirement and as long as the good load and my Board are willing, it won’t be anytime this year.

Thank you for your time. Stay well and we look forward to seeing many of you once again when things return to normal. Now Steve will review the first quarter.

Steve Strah

Good morning. It’s great to speak with you today.

As always, you’ll find all reconciliations along with other detailed information about the quarter in our strategic and financial highlights document that’s posted on our Web site.

Now let’s review our results. We reported first quarter GAAP earnings of $0.14 per share. Our GAAP results included $318 million non-cash after tax pension and OPEB mark-to-market adjustment that we were required to recognize when FirstEnergy Solutions emerge from bankruptcy at the end of February as an unaffiliated independent company, now called Energy Harbor. This adjustment was considered was consistent with the range we provided on our fourth quarter earnings call. I will revisit the status of our pension funding and liquidity position later in my comments.

Adjusting for this charge as well as other special items, first quarter operating earnings were $0.66 per share, which is above the midpoint of the guidance we provided on our last earnings call. In the distribution business, earnings decrease compared to the first quarter of 2019. Lower revenues were driven by the impact of mild weather on customer usage. This was mostly offset by Ohio decoupling revenues, as well as incremental rider revenue in both Ohio and Pennsylvania.

First quarter 2020 distribution earnings also decreased due to the absence of Ohio DMR revenue, higher depreciation expense and net financing costs, which offset lower expenses. Customer usage decreased compared to the first quarter of 2019 on an actual and weather adjusted basis, heating degree days were approximately 18% below normal in the first quarter of 2019. This drove a decrease in actual residential sales of 12.6% compared to the first quarter of 2019.

On a weather adjusted basis, residential sales decreased by 1.3%, compared to the same period last year. We continue to see modest growth in customer count. In the commercial customer class, first quarter sales decreased 7.5% on an actual basis and 1.6% when adjusted for whether compared to the first quarter of 2019.

And finally, in our industrial class, first quarter load decreased 3% compared to the same period last year. Consistent with our fourth quarter, we only saw growth in the shale gas sector, with declines in other major sectors in our footprint.

Looking at first quarter results in the transmission business, our earnings increased primarily due to higher rate base at our formula rate companies related to our continuing investments in energizing the future program. And in our customer segment, first quarter results primarily reflect lower operating expenses.

Last quarter, we discussed our pension performance for 2019 and its impact on future funding requirements. I’d like to update that today in light of market volatility in our pension remark from February 26 of this year.

As we told you on the fourth quarter, the funded status of our plan was 79% at year end, the strong performance of our plan investments in 2019 resulted in a significant reduction in our plan funding requirements in 2022 and 2023 of about $300 million.

At our February remeasurement, our funded status was 77% and our funding requirements decreased again slightly. From $159 million down to $140 million for 2022 and from $375 million down to $360 million for 2023. Our conservative asset allocation has served us well so far in 2020. Back in mid 2019, we made the decision to move nearly $1 billion of plant assets out of public equities into cash. At the end of 2019, we held only about 25% of total assets in equities.

We also have a good story when we’re looking at pension as of the end of the first quarter, while the S&P was down 20%, our assets declined only 4.4% as of March 31. After our fourth quarter call, but prior to market volatility related to the virus, we successfully completed refinancing of $1.75 billion in FE Corp debt at a blended rate of 2.9%. That transaction was executed at the best rates ever seen in the utility space.

In March, we completed a $250 million debt financing at MAIT, and in April, we completed a $250 million debt financing at Penelec.

Finally, in February, we used the proceeds from our senior note issuance, together with cash on hand to fund the final settlement payment of $853 million to Energy Harbor upon their emergence. The remaining proceeds from the $1.75 billion corp debt issuance were used to refinance $1 billion in bank term loans.

Our maturities are manageable and our liquidity position is strong. We have remaining debt maturities of only $800 million this year, including $50 million at Toledo Edison, and a $500 million term loan at FE Corp, which we plan to refinance this summer.

We project liquidity of approximately $3.5 billion over the next 12 months and our liquidity facilities are committed until the year end 2022. We do not issue commercial paper. So we’ve avoided liquidity issues experienced by many others in the industry over the past two months.

Before I turn the call over to your questions, I’d like to reiterate FirstEnergy’s overall value proposition, which is very simple, but also very unique, especially in periods of extreme volatility and uncertainly, like we’re facing today.

FirstEnergy is a low risk fully regulated, stable and predictable wires utility that spans five states, including providing scale and diversity. Our 6 million utility customers provide revenue stability. Two-thirds of our distribution revenues stem from our residential customers, which are higher margin, while only one-third is generated from our C&I customers, which are lower margin.

When combined with Ohio decoupling, this mix partially insulates FirstEnergy from recessions. We have very good regulatory relationships in our jurisdictions. And our current regulatory calendar is light through our 2023 planning period, resulting in low regulatory risk across our footprint.

We invest $3 billion annually across our service area and we have a long pipeline of regulated capital expenditures. More than 60% of our investments are under formula rates and riders that minimize regulatory lag and provide timely return on and returns of those investments.

One-third of our earnings come from FirstEnergy transmission, which is not influenced by near-term changes in customer load and is primarily supported by capital programs mandated by PJM or required by FirstEnergy to maintain safe, reliable transmission service across our very large footprint.

We are an investment grade company targeting BBB credit ratings from all three rating agencies. Our liquidity is adequate at $3.5 billion. Our access to the capital markets is season, proven and remains very strong. In combination, all of these attributes support an attractive CAGR as well as a sustainable dividend that management aspires to grow, both of which are strongly desired by true utility investors.

And finally, our management team has a proven track record of meeting or exceeding its commitments. Thank you. And now let’s take your questions.

Question-and-Answer Session

Operator

Thank you. We will now be conducting a question-and-answer session. [Operator Instructions] Our first question comes from the line of Julien Dumoulin-Smith with Bank of America. Please proceed with your question.

Julien Dumoulin-Smith

Good morning team. Thank you all and hope you all are well. I wanted to follow up just to come back to where you started the conversation actually. Can you talk about more on the operational side, how employees are handling the situation and how you think about the return to work, especially across the very different states that you operate in? And then perhaps in tandem with that, if I can throw in there, how do you think about executing against your capital spend plans just given having your employees dispersed et cetera as [intensity] [ph] and under what scenarios you might reevaluate your CapEx through but first on the operational and second on the CapEx?

Chuck Jones

All right. So first, Julien, operationally, I think it’s important to point out and FirstEnergy is not unique here. Our industry has prepared for business continuity, every company and part of that has been for the last couple of decades, at least a pandemic Emergency Response Plan. We dusted it off a few times over the years with MERS and SARS and H1N1 and Ebola. This time, obviously, we put it into full implementation.

The time to prepare for something like this isn’t when it’s happened. But it’s an advance when life is normal. And we put a lot of thought into how we were going to go about this. And I just tell you, I’m very proud of our entire leadership team and literally down to every single employee. They’ve all stepped up, they’ve showed creativity, ingenuity.

And I think, our operations are continuing almost as if normal, even with 7000 people working remotely, our field forces have maintained a positive attitude. We very quickly negotiated memorandums of understandings with all of our unions across the five states on how we were going to operate. They have the PPE. They have the ability to work in pods, as I said in my call, and that’s three or four employees reporting to one location as opposed to having several dozen coming into a service center and delivering materials remotely.

I think the proof is that it’s working as we’ve had nine cases at FirstEnergy for a 13,000 employee workforce. One of those cases in New Jersey, unfortunately resulted in a death. But we’ve had zero cases where the disease has been transferred at work. And I think that shows that the things that we’re doing are working. I think we can stay in this mode for a while. And I think that gives us the flexibility to be very thoughtful and deliberate on how and when we want to return to normal operations. I honestly don’t think the world is going to get back to normal until there’s widespread distribution of a vaccine for this virus. So, we’re evaluating what the new norm is going to mean in the interim.

But, to your specific question on CapEx, a big piece of our guidance in our CAGR is driven by those investments. And as I said, we don’t see any supply chain interruptions that we’re worried about right now. And that includes the workforce supply chain, because most of the significant capital investment that we’re making is being done with a contracted workforce that we lined up many, many years ago. We lined up really before we started energizing the future seven years ago.

So right now, I mean, I don’t see anything that I’m worried about taking this off track. And that’s why we’re comfortable with being able to not only reaffirm our guidance for this year, but reaffirm our CAGR.

Operator

Thank you. Our next question comes from line of Shar Pourreza with Guggenheim Partners. Please proceed with your question.

Shar Pourreza

So just in New Jersey, there’s a lot going on with the BP workload. And I know we’re still kind of waiting for the procedural schedule. But any sort of sense on whether we could see a settlement struck this year from a timing perspective, as we think about COVID related challenges, in any sense on the timing of the next IIP.

Chuck Jones

Well, first on the rate case, it got delayed, I think a little bit as everybody was responding and reacting to this pandemic. But I think they’ll get the schedule back on track here soon. Assign it to an ALJ, get a procedural schedule. We weren’t anticipating really anything to happen with a final outcome on that case this year anyway.

I think there will be opportunities along the way to have settlement discussions, if that would happen, it’ll be late this year at the earliest I would think. So I don’t — I just don’t expect much impact of that rate case in 2020. And there’s none of that in our guidance anyway.

As far as the IIP, the current IIP runs through the end of this year. And I think right now, I’m not sure that we’re even going to file for an additional IIP. We’re still evaluating it. But right now, we don’t have any plans to do that. We’ve got the investments that we’re making in capital going on in transmission and other states in our operating area. And I think we’re going to be fine with the service to our customers in New Jersey after this first round.

Shar Pourreza

Got it. And then in Pennsylvania, it’s been quiet, because you’re sort of experienced in Ohio and kind of the latest macro uncertainty, maybe strengthen the case for seeking decoupling which has been available. I mean, some of these usage trends may structurally change over the long term as you kind of obviously highlighted as a new normal or is kind of this DISC adequate for you until you kind of file the next GRC?

Chuck Jones

We don’t have any plans for a broad rate case activity in Pennsylvania for the next several years. And I think that LTIP and the DISC mechanism are working fine. And they’re generating the type of investment that’s needed for customers and they’re generating reliable returns for shareholders without lag. So I think the way things work in Pennsylvania are working fine and I don’t see any reason to change it.

Shar Pourreza

Perfect. Thanks a lot guys. That was it this morning. And Chuck by the way, that’s for the record, you do look very young, not old. Thanks, guys.

Chuck Jones

Thanks Shar.

Operator

Thank you. Our next question comes from line Stephen Byrd with Morgan Stanley. Please proceed with your question.

Stephen Byrd

Most of the key questions have been addressed. I did have one broader question. Just as we think about going into 2021. If we do have an extended economic downturn, so recovery is slow. How do you think about just your CapEx plans, ability for customers to handle the impact of the CapEx? Is that viewed as just, this is critical work that needs to be done? Or is there any just consideration of customer ability to pay if we do have a very extended pretty severe economic downturn? How do you just think about that longer term?

Chuck Jones

Well, we haven’t exactly seen a lot of load growth across our footprint over the last half a dozen years or so really since the last big recession. And so, the impact on customers is always something that we’re very thoughtful about as we make these investments. But I do believe these investments are investments that are needed. The transmission and distribution infrastructure we have at FirstEnergy is old. It’s in some cases in need of repair and modernization. I think that the automation that we’re adding in some areas, we’re making these changes to serve customers better. And I think we’re doing it in a way by moving it around from state to state and so forth, that that we are constantly watching out for the impact on customers and keeping our bills very moderate and keeping our rates amongst the lowest in pretty much every jurisdiction that we work in. So I think we keep an eye on that all the time. And I don’t see anything happening here that’s going to cause us to have to significantly adjust our plans.

Stephen Byrd

Well, that’s a thoughtful answer that makes sense. Maybe just one last one. I think you gave a very thorough response on just COVID-19 impacts. If we zeroed in on the supply chain, if we do have an extended shelter in place dynamic, are there certain elements of the supply chain that you focus on more as being sort of more at risk if conditions deteriorate, or overall? Do you feel fairly good about the supply chain dynamic?

Chuck Jones

As of right now, as I said in my prepared remarks, we’re not seeing anything that concerns us. We made a decision at FirstEnergy a number of years ago, four, four and a half years ago to implement a Buy America strategy. So we don’t rely a whole lot on foreign supplies. We’re 80% plus buy in from American made — buy America made products from American companies. And I do think that well, in the short-term — I think in the short-term, the risk was bigger there. I think you’re going to see the states have to reopen. And I do think from our experience, there are ways to bring people back to work and give them the PP and take their temperatures. And introduce at some point, antibody testing and take steps to get people to work and still maintain a healthy workforce and not have this virus spread. So, I think you can accomplish both. Right now, I’m not concerned, I think that our supply chain is going to be fine.

Operator

Thank you. Our next question comes from line of Steve Fleishman with Wolfe Research. Please proceed with your question.

Steve Fleishman

So just a question on the — maybe just a little bit of baselining on what you’re assuming for sales and in terms of like the length of the downturn here? Is there, I know your sensitivity is relatively low compared to a lot of other utilities. But just be good to have a rough idea of what kind of economic or base assumption you’re using for the downturn from the virus and the like in your planning? And how much have you sensitized that?

Chuck Jones

So let me let me start with an answer here. And then maybe I’ll ask Eileen to step in and provide some additional color. But, my view Steve is, it’s a jigsaw puzzle that we’re still trying to piece all the parts together on. We talked about the impact of the stay at home orders driving residential usage up 6% to 6.5%. And the fact that 65% of our distribution revenues come from this segment, the reduction in load on the commercial and industrial is about 13%. And, but as I said 80% to 90% of that is collected through customer charges and demand charges, and then you layer on top of that, the decoupling in Ohio, which represents about 20% of our load.

When you put that all together, I’m confident that that there’s not going to be any material swing in weather adjusted revenues that are going to take us off track from delivering on our guidance, because, or I wouldn’t have reaffirmed guidance. So, in the end, we don’t have a final number that I can give you yet. But I can tell you this, we just added one quarter on top of five years now of meeting or exceeding every midpoint that we’ve given you. And I don’t plan to break that record. So, I do think there will be continued lingering effect with the C&I even after the stay at home orders begin to be reduced.

But also, as I said, with our company, I don’t expect 7000 people to come back to work all at once. So I think some of the positive impacts in the residential segment are going to continue for a while to maybe not at 6% to 6.5%. But, at some level, above normal. So Eileen, you have anything you want to add?

Eileen Mikkelsen

Thanks, Chuck. I think you really nailed it. We continue to look at this very carefully. The only thing I would add is that in addition to our own models, we’re looking very carefully at economic indicators from Moody’s and others to inform our view of the forecast going forward. And other than that Chuck spot on what you had to say.

Steve Fleishman

Okay. So my read of that is that the way your revenues work and that the part that’s locked up and not volume sensitive plus the way, you’ve got things locked up with C&I more on a demand charge, kind of not that you’re fully protected, but it gives you just a decent amount of protection to deal with this, even if it extends longer than people generally think.

Chuck Jones

Yes. And I’ll add, Steve said that a third of it comes from transmission, which isn’t load dependent.

Operator

Thank you. Our next question comes from line of Charles Fishman with Morningstar. Please proceed with your question.

Charles Fishman

I’d like a follow-up on that last question. On Slide 4, where you show like 80% to 90% of C&I is fixed rates? How does a good portion of that fixed rate is a demand charge? How typically does that reset realizing your — you got numerous jurisdiction. But does that demand charge reset on an annual basis typically, so even though it doesn’t impact you this year, if a commercial or industrial customer cuts back on load, would that impact you next year on that fixed component?

Chuck Jones

For the fixed component is basically something that resets every month. So and their monthly bill is based on what the peak demand they hit in that month is. And so it’s not directly tied to the throughput that that we’re talking about when we say usage is off by 13%. It’s the first the fixed customer charge and then the demand charge. So, now if you’ve got a factory that was working three shifts and it’s now down to work in one shift, the demand charge from that one shift is essentially going to set the bill.

So, and we don’t know — we don’t reset rates every year. So our rates are in place until we have a — until we have a rate case. Then, the demand charges are what the demand charges are, and they’re based on the demand the customer hits every month. So, Eileen, anything you want to add there?

Eileen Mikkelsen

No, Chuck. Thank you.

Charles Fishman

Chuck, wait, maybe try to put it in a more simpler fashion for me. Let’s say you have a factory that’s got three lines of production. And because of a continued downturn, they said that we’re only going to use two lines of production. Well, obviously that cuts down on the demand. Then, what you’re saying here is that fixed component does go lower after a while correct?

Chuck Jones

It can go lower in that scenario, it would likely go lower for that customer.

Charles Fishman

And then at that point, you’d have to wait for a rate case to reset rates and recover that correct?

Eileen Mikkelsen

Chuck, if I could jump in here. When I’m sensing up, pardon me, when I think about those demand rates in the scenario you just indicated, we have billing demands that are set on a monthly basis, what’s the peak demand you hit on a monthly basis. So if a customer’s running three separate shifts, and they go to one shift, their peak demand isn’t necessarily as Chuck said earlier going to change as a result of that elimination of those two extra shifts because it’s not an aggregate demand over the course of the day rather, it’s the peak demand during that day, so we would expect that to be, the billing demand to remain in place based on that one shift example you just used.

Charles Fishman

Well, but I guess what I’m saying is, what if a customer makes a conscientious decision to lower its demand by reducing the size of its production? So, irrespective of number of shifts?

Chuck Jones

In that case there will be a reduction in that customer’s bill, but paying out when you think about across the entire segment, not all customers are going to have the ability to do that. And, all we’re trying to tell you is, our experiences during past recessions, that even know throughput might be off by 13% revenue isn’t off by that same amount because of these fixed charges and demand charges that occur in their bills.

Operator

Thank you. Our next question comes from line of Michael Lapides with Goldman Sachs. Please proceed with your question.

Michael Lapides

Thank you for taking my question and appreciate you taking all the time on today’s earnings call. Actually, I have a question about customer counts, not necessarily demand, but just the number of customers you serve. Can you talk about trends you have seen both on the residential side and on the industrial side, just in terms of the number of customers served over the last couple of years? Can you talk about what happens coming out of 2008, 2009 to your customer counts across the residential and industrial level?

Chuck Jones

Well, the 2008, 2009 numbers are not in my brain anymore maybe they’re in Eileen’s or someone else’s. But obviously, we lost a lot of customers. I know the numbers that stick in my brain, we lost 25% of our industrial load in one year from part of ’08 to end of ’09. And I think, I remember in Ohio I think it was 50,000 meters that we lost in Ohio alone. So we are seeing growth in meters every year. Maybe Eileen can fill in some of those numbers. But the growth in meters is pretty much also being offset by the fact that energy efficiency is working against that growth, which is what results in pretty much flat to no low growth across our footprint. Eileen, you have any thing on the numbers?

Eileen Mikkelsen

Yes. Thanks, Chuck. I would just say our residential customer counts have grown quarter-over-quarter. In quarter one in 2020 versus quarter one in 2019, just about a 0.5% in customer growth counts. So we’ve seen that quarter, that trend continuing each and every quarter for a number of prior quarters.

Michael Lapides

Got it. Thank you and just real quick. That’s an easy one. Can you remind us what is the load growth assumption in your 6% to 8%, in your 5% to 7% long-term EPS growth rates?

Chuck Jones

Steve, do you want to take that one?

Steve Strah

Yes. Michael, we’re assuming basically load to be flat over our planning horizon. So when you look at the trailing 12 months, we see that we’re slightly below that right now. But that’s what we have baked into both these 6% to 8% and the 5% to 7%.

Michael Lapides

Got it. And you are still assuming in the 6% to 8% that it’ll still be flat.

Steve Strah

Yes.

Operator

Thank you. Our next question comes from line of Paul Patterson with Glenrock Associates. Please proceed with your question.

Paul Patterson

I’m just thrilled, I guess, just sort of tie things up here with all these questions on the economy. If we have a deep recession, are you guys saying that you guys are relatively economically or you guys are relatively insulated or immune, I guess to a big slowdown, because the one thing that comes to mind here is that, we’re potentially at least in this region, looking at businesses maybe never reopening. It’s not out of the question here. I mean, retail establishments, just in general.

I’m just trying to make sure that I get completely clear. Are you guys saying that basically, if we have a big deep, long-term recession, you don’t see any regulatory changes or anything that could impact you guys?

Chuck Jones

I think what we’re trying to say right now is that the diversity of our footprint, the diversity of our revenue streams with a third being transmission that’s not load dependent. And 65% of the distribution revenue being residential and that piece at least as long as the stay at home or there in fact is growing that we see nothing that significantly give you a range of earnings of $0.20 that’s going to take us outside of that range. So we were comfortable reaffirming our guidance.

And as I said, I mean we’re a big company and we have over $2 billion of O&M related expenses in our company and if we need to get a little more diligent at O&M discipline to offset some of what might be happening on the meter side of things, we’ll do that. We’ve got a lot of moving parts as being a regulated utility that we can — we can work to deliver on our commitments.

So I think the way to take that is, yes, I’m certain that there are going to be in particular small businesses that don’t reopen after this pandemic. They just don’t have the working capital and the liquidity to survive something like this with no revenues coming in. But, I do think in time, somebody will replace them, because the services they were providing are needed by society. So I think, it’s going to be deeper than what maybe a lot of people think and maybe more U-shaped than what some people think. But I think we’re built to be able to handle it is the way I would say at FirstEnergy.

Operator

Thank you. Our next question comes from line of Sophie Karp with KeyBanc. Please proceed with your question.

Sophie Karp

I want to just to follow up on the recovery mechanisms that you have. So outside of Maryland, which has established that COVID, specific guest rider, which riders or trackers, I utilize now that your jurisdictions to track the COVID related costs and how easy is it I guess, to separate what’s COVID and what’s not COVID at this point? Thank you.

Chuck Jones

Well, so the biggest piece that I think a lot of people have been worried about is ultimate uncollectible expense. And in our case, we have recovery mechanisms in place in Ohio and New Jersey already as part of our normal operations to recover those. I think we’re having conversations with other regulators. And I think with [indiscernible] guidance, I think you’re going to see regulators across the country realize that there’s going — these are unique times and there’s going to be a unique approach. And as I said, for the Maryland Public Service Commission, be the first ones to step out and take the lead on that. They should be very proud of their leadership. But, the costs so far aren’t anything that have concerned me and right now, I’d say we’re just treating it as another operating challenge that we need to overcome and still deliver on our commitments and over time, if they grow, we’re going to be working with our regulators and we’re going to be watching what others do. We’re not normalizing any of these costs. Because, like I said, I’m treating it as a normal operating challenge today.

But in the end if our whole industry starts to normalize COVID costs out, then I’m not going to put FirstEnergy at a disadvantage by not doing that. But right now, if these costs are not — they’re not anything I’m overly concerned about. We didn’t have anything in the first quarter that we felt any need to have any special treatment for. And we’re having discussions with our regulators in West Virginia and Pennsylvania to kind of fill the gaps similar to what Maryland has done.

Sophie Karp

Thank you. And then real quick on the CapEx. Are there any particular types of project or any particular type of work maybe that cannot be done efficiently with social distancing that you may be looking to defer and maybe bring forward something else? Have you looked at that yet?

Chuck Jones

No. I don’t there’s anything that we see that’s problematic. If you think about our CapEx plan then I’ve shared these numbers in the past. We spend $3 billion in average $1 million to $1.5 million increments. So they’re smaller projects for the most part. But our crews have been very creative and figuring out how to work safely. And they’re doing a fantastic job. We had two pretty significant storms come through with over a half a million customer outages. And they restored service as fast as if not faster as we would do under normal operations. They are rising to the occasion and saying, “Look, we’re essential workers and we’re going to prove that we’re essential,” and they know the challenge of keeping the lights on to 6 million families and businesses is very important right now. So I don’t see anything there that we are worried about either.

Operator

Thank you. Our next question comes from line of Jeremy Tonet with JPMorgan. Please proceed with your question.

Jeremy Tonet

Just wanted to pick up on the kind of bad debt expense question. And I was wondering if you could provide some detail with regards to what that looked like in 08′, ’09. How that, we’re very early in here. But how that now compares to then. And when you have — you talked about recovery mechanisms in Ohio, New Jersey, is that everything or just any more color there would be very helpful?

Chuck Jones

Well, the first thing that I would say, and I’ve been in this business for 40 years, I don’t think it’s fair to assume that every customer who can’t pay their bill today is going to end up being a bad debt. My experience is customers want to pay their bills; they don’t want a black mark on their credit history. And as long as we’re flexible and work with them the right way, we can generally get to where we don’t end up writing off a lot of what’s going to get backed up here today. And we are getting — we’re worth thinking through how to be even more creative and more flexible and particularly working with our C&I customers, where in the past, we did not have payment arrangements for C&I customers. And we’re looking at how we do that going forward again to help them ease back into business and get back up to more of a normal operations without having this bill be something they have to have to settle up day one.

So in Ohio, and New Jersey, as I said it only becomes an uncollectible expense when we write it off. And we have the ability then to recover that from — other customers to our existing rates, a little bit of a lag in New Jersey. We now have that ability under what Maryland did. And I think all of the companies in Pennsylvania will get together and have discussions with the Pennsylvania Public Utilities Commission, still early on in this process. So while Maryland acted quick. The other regulators are looking at all of these COVID related costs too.

Operator

Thank you. Our next question comes from line of Durgesh Chopra with Evercore ISI. Please proceed with your question.

Durgesh Chopra

Am I sorry if I missed this, but I just wanted to ask you about your credit metrics and given the — sort of you’ve talked about the decoupling the transmission rate base. What do you think, how are you positioned versus your target credit metrics this year and maybe 2021. And then second part, maybe any color that you can sort of provide us with in terms of your conversations with credit rating agencies. Thank you.

Chuck Jones

Yes. So I would just start by saying, again, I don’t think there’s anything significant to report. We still plan on no new equity until 2022. And then up to 600 million a year in 2022 and 2023. The metrics this year are turning out, this is the transition year with the delay in the Energy Harbor emergence from 2019 to this year.

So the rating agencies are all looking beyond this year anyway. But excluding you Energy Harbor, we’re in good shapes with all the current thresholds. We’re at BBB with Fitch today. S&P revised our upgrade threshold to 12 from 13. And I think we will eventually support a positive outlook for us. We’re having discussions with Moody’s, about the upgrade threshold. And I think that’s the important thing. As our current conversations with the rating agencies are focused on the top-end and what is needed for upgrades rather than where we’ve been in the past, which is worrying about the bottom end. And I think one of the key drivers for the discussions that we’re having is, is our low risk profile that the agencies are now starting to see. The impact of the pandemic is a perfect example of our change in risk profile. We’re dealing with it. We have no material change in our earnings, no material change in our pension funding status, no material change in our credit metrics.

And we’re able to do that because of the diversity of our footprint, the stable and constructive regulatory environments, 55% of our revenue coming from residential customers. And I would just tell you there’s — we have a very, very small generation footprint. Other large T&D companies like ours with 6 million or, multi-million customers have large generation businesses, even if regulated they support that. We only have a couple power plants left and so we don’t have the risk of the generation side of this business either. And there are only one or two other companies in our space, I think with the low risk profile, that we enjoy at FirstEnergy. And I think that’s what’s forming the foundation of our discussions. We’re focused on ultimately get into BBB with all three rating agencies and then a plan to stay there long term.

Operator

Thank you. Ladies and gentlemen, our final question this morning comes from the line of Andrew Weisel with Scotia Bank. Please proceed with your question.

Andrew Weisel

Thanks for squeezing me in here. Appreciate all the details on mechanisms and downside protections. One thing I just wanted to ask about was, what’s the latest thinking on smart meters in New Jersey following the end of the moratorium?

Chuck Jones

Well, I think that we’ll engage in the conversations with the administration and the BPU in New Jersey. And we’ve got a lot of experience now with almost 2 million of them in Pennsylvania that we’ve already installed. We’re beginning the process with grid mod in Ohio, where we will install around 700,000 in Ohio. I think that puts us in a position to really share in New Jersey what some of the benefits and some of the risks are. And we’ll engage in the discussion and ultimately, that’s where the policymakers in New Jersey want to go. Then we’ll install a million smart meters in New Jersey just like we have in others states.

Andrew Weisel

Okay. Have you noticed any change in interest to your appetite from regulators or politicians during this stay at home period?

Chuck Jones

I think under — the governor introduced his new energy master plan, just shortly before this pandemic hit. And I think that right now, everybody in the state government, including the BPU are focused on how to best get through this pandemic right now. So I think it’s — those discussions have been put off and they’ll get picked back up, once New Jersey gets back into a kind of safe and healthy more normal operations.

Andrew Weisel

Got it. Okay. Then one last one, if I may, I might be looking for something where there’s nothing, but the new slide deck described the dividend as sustainable. And you mentioned that management aspires to grow it. Is that sort of a potential softening of the dividend policy? Or can you share your latest views on the dividend growth outlook and if that’s changed at all over the past few months?

Chuck Jones

I think you’re reading into something that’s not there. Our dividend policy is what it is. And we’re kind of at the high-end of that range right now. So, I think that’s more what it’s signaling is that, we are in the high-end of the range that we committed to and so I don’t know that you can expect one every single year but that’s not my decision, that’s our Board’s, and we expect to honor the dividend policy that we’ve communicated.

Andrew Weisel

Sure. Okay, good. I just wanted to be sure there was no change in thinking. Thank you so much and stay safe and healthy.

Chuck Jones

All right, well, thanks to all of you. The good call, it’s good to have a call where we’re talking about regulated operations. I can’t say running a regulated utility is boring right now with this pandemic, but I’m proud of our team, as I’ve said repeatedly, and we’re going to get it — get through this just fine. We’re going to deliver on our commitments; we’re going to keep our employees safe and healthy. We hope all of you can stay safe and healthy too. And look forward to seeing you in person when that makes sense again. Thank you. Take care.

Operator

Thank you. This concludes today’s teleconference. You may disconnect your lines at this time. Thank you for your participation.

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