NRG Energy Inc
NYSE:NRG
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NRG Energy Inc
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Ladies and gentlemen, welcome to the NRG Energy, Inc. First Quarter 2020 Earnings Conference Call. At this time, all participants are in a listen-only mode. After the speaker’s presentation, there will be a question-and-answer session. [Operator Instructions]
I’d now like to hand the conference over to [Technical Difficulty], Kevin Cole, Head of Investor Relations. Thank you. You please go ahead sir.
Thank you. Good morning and welcome to NRG Energy’s first quarter 2020 earnings call. This morning’s call is scheduled for 45 minutes in length and is being broadcast live over the phone and via webcast, which can be located in the Investors section of our website at www.nrg.com under Presentations & Webcasts.
Please note that today’s discussion may contain forward-looking statements which are based on assumptions that we believe to be reasonable as of this date. Actual results may differ materially. We urge everyone to review the Safe Harbor in today’s presentation, as well as the risk factors in our SEC filings. We undertake no obligation to update these statements as a result of future events except as required by law.
In addition, we will refer to both GAAP and non-GAAP financial measures. For information regarding our non-GAAP financial measures and reconciliations to the most directly comparable GAAP measures, please refer to today’s presentation.
And now with that, I’ll turn the call over to Mauricio Gutierrez, NRG’s President and CEO.
Thank you, Kevin and good morning, everyone. And thank you for your interest in NRG. I'm joined this morning by Kirk Andrews, our Chief Financial Officer. Also on the call and available for questions we have Elizabeth Killinger, Head of our Retail Mass and Chris Moser, Head of Operations.
Before we begin, I would like to take a moment to say from everyone at NRG, we sincerely hope that you and your families are well and our thoughts are with those impacted by the COVID-19 pandemic. We have never been clearer how critical electricity is to our way of life. And now more than ever, our communities are relying on the service that we provide to homes and businesses.
I want to thank our essential employees who are on the front line safely operating our power plants and supporting our customers. These employees continue to impress me every day with their commitment and courage during this unprecedented time.
Turning to Slide 3, I’d like to start by highlighting the three key messages for today’s call. First, we initiated a comprehensive response to COVID-19 focus on maintaining safe and reliable operations. Our #1 priority remains protecting the health and well-being of our employees. So they can safely deliver electricity and keep the lights on for our customers and communities. Second, given the changes that we have made to our integrated business, we were able to deliver strong results during the first quarter and reaffirm our full year financial guidance. Third, and as we promise on our February earnings call, we are providing enhanced disclosures on our business, including the introduction of new integrated regional segments.
Turning to Slide 4, I want to talk to you in greater detail about our response to COVID-19. Our top priority have been protecting the safety and well-being of our employees. On January 21, one day after the first confirm the U.S. case, we activated our crisis management team to ensure we were prepared for any scenario. On March 17, we closed our offices and transition employees to remote work. We have remained fully operational during this time with over 95% of our office personnel working remotely. While we closed our offices to non-essential personnel, we also have employees who provide critical or essential services and continue to work at our power plants and in offices every day.
As part of our commitment to protecting their health and safety, we introduced health streaming guidelines for those continuing to work onsite. Initiated deep cleaning protocols, enacted the strict social distancing guidelines, restricted to access to offices and power plants and implemented staggered staffing for essential functions. We have also expanded the health benefits for all employees to include access to virtual doctors and awarded brands from our NRG employee relief fund. These additional resources are intended to protect our employees and their families.
With respect to our operations, the impact has been limited. A few outages were delayed due to COVID-19 issues. However, none of them had a material financial impact or reliability implications. Our spring program included 84 outages and a nuclear refueling at STP. So we are well prepared for the summer months. We did stop work at all non-essential projects including our Encina demolition project in California. We have also paused face-to-face retail sales activities to support the safety and well-being of our team and communities.
Recognizing that some of our customers have been financially impacted by COVID-19, we temporarily paused all their fees and electric disconnects and offered deferred payment plans to provide temporary relief. We also work closely with the PUCT another Texas market participants to create a solution that extends additional assistance through mid-July to low income customers and those facing significant financial hardship as a result of COVID-19.
In April, we announced a pledge of $2 million to relief efforts aimed at those on the front lines who needed the most. This includes funding and critical safety supplies to first responders who are in desperate need of personnel protective equipment. Community lead relief funds for small businesses, which have been devastated as social distancing and shelter in place, guidelines have forced many to close for months. And teachers and educators who play such a pivotal role in our communities where we live and work. We have began activities to return our employees to the new normal operations prioritizing their safety and well-being.
Now moving to on to our financial and operational results for the quarter on Slide 5. We achieved top decile safety performance and delivered $349 million of adjusted EBITDA, almost a 5% increase from the same period last year. These results were driven by the addition of stream energy and margin enhancement initiatives partially offset by mild weather across our core markets.
To put the mild weather in to context, ERCOT and the Northeast saw temperatures that were 20% and 17% warmer than the 10-year normal for the first quarter. We are also reaffirming our full year guidance based on our expectations of a gradual reopening of our economy during this summer and the stability of our integrated platform. So these are unprecedented times. And expect most of the adverse impact from COVID-19, who come from customer payment related items like bad debt. At this point, we estimate that to be around $50 million. We will look at and studying this impact through prudent cost management and ERCOT's relief fund.
During the quarter, we implemented our infectious disease and pandemic plan to ensure business continuity as we discussed in the previous slide. We also updated our reporting segments during the quarter and are providing enhanced disclosures which I will discuss in greater detail later in the presentation. These disclosures are intended to help you think about our business, in the same way we manage it. I also believe, they will help demonstrate the stability of our ERCOT platform that we have long talked about, but which was difficult to illustrate when retail and generation went up off as separate businesses.
Finally, on the last earnings call in late February, I spoke at length about our sustainability program and our commitment to transparency. To that end, we just publish our 10th annual sustainability report. Our comprehensive sustainability framework is foundational to the long-term success of our company. One of the key metrics is the speed that which are decarbonizing our business. As you will see, we are now 83% of the way to achieving our 2025 goal and have clear line of site to get there.
Moving to Slide 6, I want to highlight some of the impacts we are seeing on electric demand in our core markets. In the upper right hand side of the slide, we have estimated year-on-year weather normalized changes in load for April. As you can see, electric demand have been impacted across the country with the clients anywhere between 6% to 9%. Except in ERCOT which continues to show resilience and it is down only 2%. Even within the ERCOT, we are seeing significant differences between West Texas and the rest of the state driven primarily by the impact of lower oil prices in the Permian region. These differences are not only regional, but also by customer class as you can see in the lower right hand side of the slide.
Residential remain, which makes up around 30% of ERCOT peak electric demand this time of the year is up 7% for the month of April. While small business and C&I have been negatively impacted. The point I want to make here is that the impact to a specific companies will depend on the customer mix in their portfolios. In our case, we are heavily weighted towards the Texas residential customer.
Now looking ahead into the summer, Texas already began a partial reopening of the economy. This suggests that the severe impact to small businesses we have seen in April may ease as the economy reopens. Conversely, the impact on the oil patch may just be getting started. I will seem to remind everyone that our largest exposure in ERCOT is to residential demand and so far that has been robust. The impact to summer load is difficult to assess at this point, but I can tell you that summer prices will be dependent on wind production and weather.
Finally, the long-term outlook for ERCOT from our perspective will remain robust. We know that reserve margins are dependent almost exclusively on new renewables coming online in the next few years. No doubt COVID-19, and low oil prices will have an impact on demand. It’s difficult to know how much at this point.
We have no new renewables PPA this quarter, which is indicative of a slowdown in new renewable development. How much these two things offset each other is going to the turning scarcity prices going forward. Now, based on where the forward curve is not much scarcities assuming the forward prices, which is not helpful for new renewable developments or any new development for that matter. This is why we think reserve margins will be tighter than what we have seen in the CDR.
So with this market context, I want to review how we are positioned as a company to perform during this unprecedented period on Slide 7. Since I took over as CEO over four years ago, we deliberately evolved our business from a highly levered IPP to a more stable and predictable integrated power company. During this time, we simplify and streamline our portfolio, achieve what we view as an investment grade balance sheet, establish a transparent and compelling capital allocation framework and made sustainability, an integral part of our foundation. While the stock price doesn't reflect it, we expect all the good work we have done to be reflected in our stable earnings as we successfully navigate the current downturn.
As you can see, we rebalanced our portfolio by selling non-core and underperforming assets to better match Retail Load with Generation. By integrating these two complimentary and counter cyclical parts of the value chain, we have significantly stabilized our earnings. As you can see in the new segments, our business is heavily weighted towards residential costs of consumers, which has proven to be a more resilient group during this period particularly in Texas.
Second, our balance sheet have never been stronger. Last year, we’ve reached our goal of driving our net debt to EBITDA ratio within our target investment grade metric range of 2.5 to 2.75 and to continued operational performance, we expect to drive this ratio to the conservative end of that range this year. We remain in close dialogue with the rating agencies and we continue to target investment grade ratings over the next 12 months.
Our balance sheet strength goes well beyond these metrics. We have done a good job in managing our maturity schedule and liquidity. Our next maturity is not until 2024 and each year's maturity is size to be less than anyone's year’s free cash flow. Our liquidity also remains strong at approximately $2 billion.
Next, on capital allocation, all our actions to stabilize and right size our business have created tremendous financial flexibility. And now with our deleveraging program behind us, we're focusing all our excess cash in 2020 and beyond on perfecting our business model and returning capital to our shareholders.
Last year, we established a longer term framework built upon a commitment of value creation through disciplined capital allocation across all cycles. With this financial flexibility, we will continue to evaluate opportunistic growth that meet our financial thresholds and return capital to shareholders through growing our dividend to 7% to 9%, combined with programmatic and opportunistic share repurchases. Finally, our comprehensive sustainability framework serves as a solid foundation to our portfolio as it is embedded in our culture, aligned with our strategy and necessary for our long-term success.
The bottom line is this. Our company is stronger today than it has ever been. We recognize that our business model is unique and relatively new. I look forward to further validating the stability of our platform through our strong execution.
Today we're taking one additional step in the evolution of our business model, and how we report results. We have more from having two distinct businesses Retail and Generation, to one integrated business with a regional focus. Therefore, we need to realign our segment reporting to match our integrated strategy and the way we operate our company.
Turning to Slide 8, we're introducing the new regional segments and EBITDA sensitivities. These segments will have the benefit of a common market structure and importantly, it will better highlight the stability of our platform. Also, the new sensitivity is now captured the full impact of the integrated business at the EBITDA level.
The Texas segment will include all activities in our value chain from customer operations to market and plant operations. In this new format, revenues will be primarily driven by Retail, while costs will be either the fuel that we buy for our power plants or the power we purchase from the wholesale market. This is exactly how we manage the business.
The integration of these two counter cyclical businesses results in long-term earnings stability from this segment, which is reinforced by the limited sensitivity to power prices shown in the bottom of this slide. The East segment will include all non-Texas customer activity and all generation assets in this.
This region is not fully balanced between Retail and Generation. Therefore, we will continue to have both revenues and costs for each business. Our focus is to better match these two parts, so we can fully integrate. The West another segment includes the conventional and renewable projects in California, the Cottonwood lease and our interest in one international asset. This segment will only have generation revenue and cost, since there is no ability to replicate our integrated model due to a lack of competitive retail markets.
Because the East and West segments are not fully integrated, the sensitivity to changes in power prices are not optimized as it is in Texas. We believe these new segmented structure better reflects our operations and regional impacts.
So with that, I will turn it over to Kirk for the financial review.
Thank you, Mauricio. Starting on Slide 10, I'll provide a bit more detail on our new segment disclosures that Mauricio just reviewed. In 2020, we're aligning our reporting segments with our integrated operating model which no longer involves managing two distinct lines of business those being Retail and Generation. Our new segments reflect our integrated regional focus with our customer facing business as a primary revenue driver and the majority of our generated -- generation and associated costs particularly in ERCOT supporting our customer load.
Our new segment financial results will provide a clearer picture of the EBITDA produced by our integrated segments by geography and is consistent with the way we manage our business one position for each market. To help you better understand our historical results in this context at the top of the slide, we've translated our 2019 results into the new geographical segments as they will be reflected in the components of our guidance going forward. Specifically, the Texas segment includes all of our customer market and plant operations within ERCOT and we will be providing the expected contribution from this segment to our consolidated EBITDA guidance range going forward. We will also be providing the expected contribution to EBITDA guidance from the remaining reporting segments, which include East, West and Corporate and are comprised of the remainder of our businesses.
On the upper right of the slide, you will find our 2019 results recast into these categories as compared to the corresponding results of our 2020 EBITDA guidance range. Later today, in addition to filing our 10-Q will also be filing an 8-K, which will contain restated financials based on our new segments on a quarterly and annual basis for 2019 as well as annually for both 2017 and 2018 in order to further assist you in comparative analysis. You will find some of this information on Slide 21 and the appendix today's presentation as well.
The bottom half of the slide provides a bit more color on both the operations within each reporting segments as well as some highlights on the key components of the integrated margins within each. Focusing on Texas, you should be thinking of our revenue line as retail revenue. While our cost to serve is comprised of both fuel costs associated with Generation supporting our load and purchase power, the support load in excess of economic generation. Going forward, Generation revenue in this segment will be minimal.
In the East, our primary revenue will be from retail sales and capacity and also include energy revenues from our plants that are not located near our load. The West is exclusively generation, where our thermal assets in California and associated resource adequacy and energy revenue, primarily comprising revenues on the income statement. While cost of goods sold will again primarily reflect fuel costs associated with those assets.
The West segment also includes our interest in the two remaining utility scale projects in California, those being Agua and Ivanpah as well as our partial interest in our one remaining international generating plant in Australia. However, all three of these interests are accounted for under the equity method, and our share of the earnings will be reported on a single line and the income statement.
Turning to the financial summary on Slide 11. NRG delivered $349 million in adjusted EBITDA and a robust $167 million in free cash flow before growth for the first quarter of 2020. Texas delivered $195 million in adjusted EBITDA, $19 million increase versus 2019, largely due to the increase in load from the acquisition of Stream which occurred in the second half of 2019. And improve margins due to the lower supply costs in Texas. The balance of our quarterly results of $154 million from East, West and Corporate was in line overall with last year's results. However, within this, we did have a few items of note worth highlighting for comparative purposes.
During 2019, we recognized the one-time gain of $27 million from the settlement of the Midwest generation as best as liability. During Q1 of 2020, due to the drop in oil prices, we wrote-down our oil inventories in the East by $29 million, which is a non-cash charge to earnings in EBITDA. Offsetting this write-down was the recognition in 2020 of $30 million in outage insurance proceeds related to outages that occurred last year.
Finally, much improved availability of our Sunrise facility in the west and the lower cost of operations allowed our adjusted EBITDA outside of Texas to remain flat versus 2019. We saw no material impact from COVID-19 during the first quarter. However, as Mauricio mentioned earlier over the balance of the year, we currently anticipate an impact of approximately $50 million due to the effects of the pandemic on customer payments, particularly bad debt expense, which we will look to offset through targeted cost management and the ERCOT Relief Fund.
Moving to free cash flow before growth, during the first quarter of this year, we received the $60 million in cash flow items I highlighted for you last quarter, which contributed to robust free cash flow before growth of $167 million. Due to the CARES Act, we expect our free cash flow before growth of the balance of the year to further improve from the delay of approximately $17 million of FICA payments into ‘21 and ‘22. As well as the acceleration of $11 million of AMT refunds that were previously expected in later years.
As Mauricio mentioned earlier, we continue to maintain strong liquidity of approximately $2 billion. However, as a precautionary measure, and to ensure we maintain surplus cash on hand in the event of stress in the banking system. During the quarter, we drew down our revolving credit facility by approximately $550 million to proportionally increased cash on hand. As liquidity in financial markets has improved, and we enter the more cash generative time of the year, we expect to repay the revolver balance back to zero. And since the first quarter, we've already reduced that balance by more than half.
Finally turning to an update on share repurchase activity. To-date, we have completed $224 million in share repurchases at an average price of $33.05 which consists of $60 million in purchases, which was remaining balance of our 2019 program and $164 million of programmatic repurchases under our new capital allocation policy.
Finally turning to Slide 12, for a brief update on capital allocation activity. Our expectations for 2020 are unchanged, with the only item of note being the increase in share repurchases year-to-date. Having now executed $164 million in share repurchases under the new capital allocation framework through the first four months of this year. We've now completed more than 40% of our targeted share repurchases as a part of our commitment to return 50% of our annual free cash flow to our shareholders, which this year totaled $675 million including our recently increased dividends.
The balance of $614 million in remaining capital, shown in green on the right of the slide remains available for accretive investment opportunities. However, should we be unable to find sufficient magnitude of strategically consistent value enhancing opportunities, we intend to allocate the balance of this unallocated capital to our shareholders.
And with that, I'll turn it back to you Mauricio.
Thank you, Kirk. Turning to Slide 14, I want to provide you a few closing thoughts. For the past four years, we have used a yearly scorecard to make sure we communicate in a clear and transparent way, our priorities and progress but also to hold us accountable. As you can see, we're starting to make good progress in some of our key objectives. It is still early in the year. And as a company, we are focusing the important summer months, and the safe return of our people to the new normal. I expect to update you all on our capital allocation plan, and the use of our excess cash in the coming months as we continue to generate robust cash flows during the summer.
So before I open the line for questions, on behalf of the entire NRG family, I want to thank our brave frontline workers and first responders for all they do during this difficult time. Angela, we are ready to take questions now.
[Operator Instructions] Your first question comes from the line of [indiscernible] with Guggenheim Partners.
Hey, good morning, guys.
Hey, good morning.
Couple of questions here. Can you -- can you start-off and maybe you could talk a little bit about the landscape of potential retail opportunities as we kind of look at the second half of the year. There's the PCT sort of rate relief program and maybe some of the lower estimates from peak demand in Texas. Maybe take some of the pressure off of the smaller ERCOT books to sell and shift maybe your focus for further buybacks is there's obviously you highlighted $600 million of unallocated cash for 2020? Do you sort of at this point, see anything that meets your hurdle rates, especially given where the stock is trading here? So a little bit of the -- so little bit of the retail environment and any potential inorganic opportunities?
Yes. So, well, I mean, no thought and I will say that definitely the bar is higher because of where our stock is. And we believe that significantly undervalued. Having said that, we are monitoring all the opportunities I mean, as you said, I think the environment has changed on the M&A side. We continue to be focused on growing our retail business, but we're going to do it in a way that not only meets on an absolute and relative basis our hurdles on an absolute basis it needs to meet our financial hurdles. But, also on a relative basis, it needs to be superior to buying back our own stock and investing in our company. So we're going to continue to monitor that. And as I said on my prepared remarks, I think we're going to -- we're going to go through the summer, which is where we make most of our excess cash, before we actually give an update on our capital allocation plan and give you further clarity on the additional 50% of our excess cash. So that's where we are on that allocation.
Got it. And then just -- can you Mauricio give a little bit more specific on your conversations with the agencies on an IG upgrade? I mean, are they getting more comfortable around the business risk profile and the retail segment? I mean, clearly, what you're displaying today is the sustainability of the model. And just going by some of your prepared remarks, it doesn't sound like you're seeing the IG timeline slipped due to COVID, as we saw maybe with one of your competitors. So just maybe a quick update on sort of how that conversation is flowing?
Yes. Well, I mean, I turn it on -- I will turn it over to Kirk because he's had very direct conversations with them. But what I will say is, I mean, I think we have executed well on the -- on our platform and demonstrated the stability. And once again, this year provides us a tail event that further demonstrates that stability. So as we have to demonstrate to our investors, we also have to demonstrate these two rating agencies. They're not that different in that respect. So but I'll just hand it to Kirk to talk about the timeline. Kirk?
Yes, so I think you covered some of the backdrop I would give as well Mauricio. So but overall, our dialogue with agencies remains active and very positive. I think overall, they continue to be satisfied with both our performance and our strategy. But obviously, as Mauricio alluded to, I mean given the current backdrop and uncertainty in the broader economy, it's not a favorable set of circumstances, certainly an immediate upgrade. But I would say the fact that both have maintained our positive outlook underscores their appreciation for our performance in our outlook, as well as our balance sheet. And, as we just said, looked at concurrent events provide an opportunity for us to prove the resilience of our platform under extreme conditions. And that would provide us a further argument towards that upgrade.
I mean, that's it understanding in the near-term, I think agencies are likely to take more prudent wait and see if you will approach to ratings upgrades. So it's reasonable for us to assume that that may extend the timeline a little bit maybe six months forward. Certainly, that's not our objective or target. But I think we have to be reasonable about the pace given the circumstances we're in. But I -- overall, based on our dialogue with the agencies, we're confident that with continued performance, investment grade remains achievable at our current leverage level, which were in line with those targets.
Terrific. And then just lastly on pursuing additional portfolio rebalancing for the East, West segment. Can you just provide a little bit more detail there?
Yes, sure. I mean, I think is -- I've said it before our generation assets are close to [load] pockets. There is significant location of value, we recognize that and our goal is to monetize and or optimize the value and maximize the value. So when the time -- when we have more clarity on the plans, we'll communicate to all of them but we are very focused on rebalancing our business just like we have done in Texas. Our goal is to continue rebalancing the East, and we're going to monitor what happens in California. So that's where -- that's the information that I can give you today.
Terrific. Thanks, guys. Stay safe and congrats on the results.
Thank you so much. Same to you.
Your next question is from Julien Dumoulin-Smith with Bank of America.
Thank you. Good morning. Can you hear me?
Yes. Good morning, Julien.
Excellent, thank you. I hope you all are well. I wanted to follow up on perhaps let’s talk sensitivities about the Retail business here. And I know you all have illustrated the successfully integrated platform, but I'm curious, as you see residential sales trending up here even relative to commercial, industrial, how do you think about that positioning you within ‘20 guidance, what might be the offset for instance customer attrition if you will as an example, but I'm curious how you would position yourself within the context of your current year guidance given the trends that you're seeing on residential and quantify that a little bit more?
Yes, so I feel comfortable reaffirming the guidance range that we provided to you. I think that, we're monitoring and we're seeing how quickly the economy reopens. And that's going to inform what happens with our customers and customers load. I think we wanted to show what happened in April, and it's pretty significant to increase on the residential customer compared to small business and C&I.
But as I said, I mean, we need to see how quickly people come back to work. I think that's going to perhaps help the small businesses is going to bring residential back to normal and C&I. We're going to evaluate, because it’s not only COVID-19, but also the impact of oil prices. But that's very, very focused on West Texas.
I think the important thing is, we wanted to quantify so far, what is our estimate in terms of the impact of COVID-19. And we are looking at -- we're going to take initiatives both on the cost management side and the relief fund to offset that.
Outside of that, I mean, I think it's just -- there are so many things that we don't control, how quickly states open, how quickly people are going to go out. I mean, we are encouraged to see that Texas already taking the first steps to reopen the economy. But I mean, I think there is still a lot to assess. Obviously the makeup of our portfolio is heavily weighted towards the residential consumer. But, we need to assess all the other hire.
Got it, fair enough. And then moving over to capital allocation and I don't mean to believe at this point, you have sort of a definitive point in mind that [technical difficulty]you around when we get the capital allocation of taking how do you think about growth versus buybacks, [technical difficulty]where they are and perhaps less obvious growth [technical difficulty] just want to kind of get a little bit more of a definitive sense on them? I mean you're thinking on the remaining and allocate?.
Yes. Well, I mean, first, I think we've made really good progress on our capital allocation, we have fulfilled our commitments with our new dividends. We are ahead of pace on our share buybacks. I mean, I think in the last call, I said, we're going to be very programmatic, but I'm not [indiscernible] and I see the significant undervaluation of our stocks. So we actually were a little bit of more opportunistic this quarter and we're ahead of pace. And then for the other 50% of our excess cash that has been planned for growth. I mean, it's early in the year, I want to see how things evolve in the next couple of months, but I feel confident that I can provide you a little -- more clarity in the next couple of months. I mean, we're not going to wait until the end of the year to provide that clarity. That's -- if that's your question, what you're implying. I mean, we're going to come back earlier than that, to provide you more visibility on that additional excess cash.
And just to clarify the last question here. With respect to attrition and bad debt trends. Any concerns -- obviously, you're referring to money on balance, but I just want to be very specific about those two pieces.
Yes, I mean customer payment items like bad debt is something that we are monitoring very closely because of -- we have many customers that have been impacted by the COVID-19. And, they are in financial hardship. We've been working very closely with the PUCT to put together a program to provide relief to those customers. We have provided you already an estimate on what we think that could be. Obviously we're going to work with a with a PUCT to offset some of that costs through their relief fund, but also, we have other levers that we're already activating to make sure that -- we mitigate the impact of that. What I described as one-time items due to COVID-19.
Thank you.
Your next question comes from Stephen Byrd with Morgan Stanley.
Hey, good morning. I hope you all are doing well.
Good morning, Stephen. Same to you.
Congrats on the good results and the increased disclosure definitely helpful. I wanted to talk about renewables opportunity. I know you didn't find anything new up, but just given the potential distress and challenges that some of the smaller developers might have, would that potentially create an opportunity to actually -- own some of these projects, rather than simply be an off-take?. In other words, could you potentially sort of -- for relatively modest capital actually takeover projects for companies that are having a hard time sort of funding their development from here?
Well, I mean, at this point, our focus is on our capital light strategy. I mean, we've been there, done that in terms of the ownership. And at this point, I prefer the strategy that we're executing. As I said, we didn't sign any new PPA during this time. So I think that should give you an indication that this thing has slowed down in the development of renewables in Texas, perhaps it's just push -- pushed out a little bit, we're very active, we're going to continue to remain active. We think that given where the company is, given the balance sheet that we have, we are an excellent an off-taker of these, and we should be signing very high quality projects. But, at this point, I don't see ourselves taking ownership of our renewable projects.
Understood. I respect that. And then just shifting over to the residential demand and just the overall demand outlook that you provided on Slide 6, which was helpful. I guess, I'm thinking, if residential demand would have remained strong throughout the summer, maybe into the fall is just we see more people at home and greater usage there. And that seems to be fairly meaningful. The margins are attractive on that side of things, how important would that be from a guidance perspective or put differently if we continue to see fairly strong trends of high residential demand, would that be meaningful in terms of the range of the guidance and push you towards the higher end of the range?
Well, I mean, without talking about where you are going to be in the guidance or not, I mean, I think it's -- it is important to recognize that our portfolio in Texas is primarily residential customers. And we have seen actually an increase in demand from those customers. Now, as you go into the summer, just recognize that perhaps April, the increased demand is much bigger than what you're going to see in the summer months, because in the summer months, you normally already have people using a lot of electricity. I mean people kids are out of school they come back to.
So we don't expect to see the same level of the impact as we go into the summer, as we have seen in April. So and also it's going to depend on how quickly the economy comes back. Right, I mean, small businesses perhaps they open gradually, they're not going to open at full capacity first. So we're assessing that. But I think it's too early to tell to start trying to make some sort of assumptions in terms of what would be the ultimate impact of our -- in our portfolio.
Obviously, if you have a 6% increase or 7% increase on residential demand for the balance of the year, I mean, that's great for us, because we have a pretty significant exposure to it, if that's what you were trying to imply, but I also want to be cautious that there's so many things that we don't control here. We are -- I think we are very well positioned. I think we're managing the -- our company and our risk well. But we are also mindful that there is a lot of things that are outside of our control, and we need to just monitor that. And if we see it, we communicate that to you.
Very fair. Thank you very much.
Thank you.
Our final question comes from the line of Jonathan Arnold with Vertical Research.
Hi, good morning, guys.
Good morning, Jonathan.
Thanks for all of the update. I just have a question on the new integrated modeling portfolio data. I think given that you are net short in ERCOT, can you just help us sort of reconcile the positive sensitivity in power prices and just how to think through that on an integrated basis?
Yes. Well, let me just start by saying that we're not net short. I think that’s -- I've heard that a couple of times and that's a common misconception. When we go into the current year, we're perfectly balanced between Generation and Retail. I mean, we obviously are going to try to optimize these two assets that we have Generation assets and Retail load. But I think we should assume that when we going into the current year, we complement the production of our megawatts from our plants, we purchased this from the market.
So I wouldn't say that we're -- that we are short.
In terms of the sensitivities, I mean, now these are integrated sensitivities at the EBITDA level, which not only the interaction between Generation and Retail on a gross margin basis, but also all this -- some of the other levels that we have to ensure that we optimize these two parts of the business. So I mean, I think the really the bottom line is -- those sensitivities we're trying to make them as small as possible. I mean, that's the whole idea of a stable platform is regardless of what prices do, whether they go up or down our sensitivity is minimal. I think that's really what you -- the key takeaways of – but since we're talking about position management, I'd like to turn it over to Chris, just do you have anything else to add, Chris?
Yes. Hey, Jonathan. One way to think about the math a little bit is -- and I'm assuming you're getting the net short because you're looking at -- we serve 60 whatever terawatts 58, 60 terawatts of load and we've got 40 terawatts expected generation. So you're saying where's the other 20? Are you guys short out there? Those numbers are true when it comes to delivery. But if you think about a couple of years, we haven't sold all of that yet. We have the opportunity to pass through price changes. So it's not fixed price. And we're short 60 terawatts for the next five years, right? That that fixed price short rolls in over time. And we can flex and change price on that. And to that extent it's not a fixed price short out there for all eternity if that helps you think about the modeling a little bit.
No, very helpful. And we’ll spend some time on the new disclosure. Thank you for that. Can I just follow one other item that Mauricio, you mentioned this kind of the bad debt number $50 million? Should we think of that? Is that just an account number, or is that a portfolio wide number? And should we think of that as something that we would persist if we have a slow recovery continues of economic hardship into next year or is that something you would -- you did mention that you said that one-time. I think in one of your comments, just maybe frame that a little further?
Yes, no, I mean, it is for that portfolio as a whole. And when I say one-time is because this is very specific to the impact of COVID-19 to customer payment related items, which bad debt is one of them. So yes, you need to think about it as -- for the entire portfolio and this is a one-time, COVID-19 related.
Okay, thank you.
I would now like to turn the call back to Mauricio Gutierrez for closing remarks.
Well, thank you, Angela. And thank you all for your interest in NRG. I hope that you are staying safe and well, you and your families and I'll be looking to talking to you in the next couple of weeks. Thank you and talk to you later.
That concludes today's conference call. Thank you for participating. You may now disconnect.