Exelon Corporation

Good morning and welcome to 2019 second quarter excellent earnings call. My name is Nora and I'll be facilitating the audio portion of today's interactive broadcast. All lines have been placed on mute to prevent any background noise. After the speaker's remarks, there will be a question and answer session. If you would like to ask a question during this time, simply press star then the number one on your telephone keypad. If you would like to withdraw your question, press the pound key. This event also features streaming audio, which allows you to listen to the show through your PC speakers. For those of you on the stream, please take note of the options available in your event console. At this time, I'd like to turn the show over to Dan Eggers, excellent senior vice president of corporate finance. Please go ahead, sir.

Thank you, Nora. Good morning, everyone. And thank you for joining our second quarter 2019 earnings conference call. Leading the call today are Chris Crane, excellent president, chief executive officer and Joe Nigro, excellence chief financial officer. They're joined by other members of excellence senior management team will be available to answer your questions following our prepared remarks. We issued our earnings release this morning along with the presentation, both of which can be found in the investor relations section of excellence website. The earnings release and other matters which we discussed during today's call contain forward looking statements and estimates that are subject to various risks and uncertainties. Actual results could differ from our forward looking statements based on factors and assumptions discussed in today's material and comments made during the call. Please refer to today's AK and excellence other SEC filings for discussions of risk factors and factors that may cause results to differ from management's projections, forecasts and expectations. Today's presentation also includes references to adjusted operating earnings and other non-GAAP measures. Please refer to the information contained in the appendix of our presentation and our earnings release for reconciliations between the non-GAAP measures and nearest equivalent GAAP measures. We've scheduled 45 minutes for today's call. I'll now turn the call over to Chris Crane, excellence CEO.

Thanks Dan and good morning everyone and thank you for joining us today. Before I turn to the financial results for the quarter, I'm going to spend a few minutes providing some key updates on a number of positive developments in our businesses over the last three months. First, we continue to move forward on our utility regulatory strategy, filing distribution rate cases at BGE, ComEd and PEPCO DC, reflecting our safety and reliability investments across those service territories. In DC, we filed our first multi-year rate case. The plan provides the necessary framework to align PEPCO system investments with DC policy goals, including grid modernization and further improvements to customer service and reliability. Joe will discuss the details in his remark. Second, last week PEPCO and other parties filed a settlement agreement at FERC for PECO's formula rate transmission rate. The settlement includes a .35% ROE inclusive of a 50 basis point ROE adder. PECO made the original filing in 2017 and we expect the final order from FERC in 2020. Third, in June we issued our annual corporate sustainability report, marking our performance and sustainability goals and priorities. In addition, the benchmarking air emissions report that found Exelon is the largest generator of zero emissions energy in the U.S., producing 12% of the nation's clean energy. Also that we have the lowest emissions rate emitting at a rate that is four times less than the next cleanest generator. Fourth, the New Jersey BPU approved ZEC payments for the state nuclear units, including our interest in sale. We appreciate the state support for the carbon free power produced by these units. Fifth, we were unable to get legislation done in Pennsylvania in time to reverse the decision to close TMI this fall. Since then there have been continued discussions on a path forward for the remaining nuclear plants in the state, including consideration of placing a price on carbon through the regional carbon trading. Sixth, we are also pleased the Trump administration decided not to impose quotas on uranium, which would have jeopardized the continued operation of commercial nuclear reactors in the United States. And finally, last week FERC issued an order directing PJM not to run the capacity auction in August. We agree with FERC's decision to delay the auction until the rules are finalized. The delay provides PJM and the state policy makers time to adjust to the commission's changes. Before I turn to the financial results, I also want to address two matters you have raised with us recently. First, we've received a number of questions from investors about the impact on our business from the steep decline in power prices. The decline presents a considerable challenge for us, but as you know, our hedging disclosures are a point in time estimate. If you have seen them move up and down in the past, we need to be thoughtful and deliberate about our response if these prices persist. And we have a variety of levers that we can pull in decisions we can make if this is the future of energy markets. We are pursuing a number of market reforms addressing the financial challenges many of our plants face. Against this backdrop, I can also again assure you that we will not operate unprofitable or negative free cash flow plants. You've seen us close money losing plants in the past, and you should expect that discipline to continue if reforms are not enacted. The bottom line is that fundamental market reforms are needed in the United States if we want to meet the nation's clean energy climate goals, maintain fuel security and reliable system, we need to sustain an increased electrification, preserving significant economic value through good paying jobs and property taxes. We'll continue to work at the state level and the national level with Burke, the Congress, and the administration to make this happen. Second, we've had, we've received numerous questions from our investors about the subpoena in Illinois from the U.S. Attorney's Office. We are cooperating fully and providing all information requested by the U.S. Attorney's Office. We simply can't comment further on the investigation, and we're not going to speculate on whether it may affect legislative efforts in Illinois this fall. What we do know about this fall's session is there are a number of stakeholders who want to see clean energy legislation enacted. Illinois lacks behind other progressive states on clean energy policy. Passing the clean energy legislation is a priority for many stakeholders, including in Illinois, including the Citizens Utility Board, Labor, the Clean Jobs Coalition, and the Renewable Community. These stakeholders want to greatly expand the renewable penetration so the state will be able to achieve the 100% clean energy target by 2030. Kathleen and her team are working with the stakeholders to help craft the legislation, the legislative package, and inform members of the General Assembly on the benefits of this legislation. It's important to remember that while we are putting a real effort into preserving the value of the generation fleet, our focus remains on the utilities. The bulk of our capital investment and growing majority of our earnings are coming from the regulated business, where we continue to see great opportunities to invest and grow to the benefit of our customers and communities. Now I'll turn to the financial results on slide five. We had a good quarter delivering earnings at midpoint range of our guidance. On gap basis, we earned 50 cents per share versus 56 last year. On a non-gap basis, we earned 60 per share versus 71 last year. Joe will cover these drivers in his remarks. Turning to slide six, operational performance of the utility was mixed during the quarter. We continued to perform at top quartile levels of cost for reliability and customer operations metrics, but our safety performance has slipped. Safety is the highest priority, and we are focused on ways to improve our safety culture and performance. Outage frequency and outage duration performance is in the top quartile for three of our four utilities with ComEd performing in the top decile. On the customer operations side, all of our utilities performed at top quartile for service level and call abandonment rate. Our relationship with our customers is improving due to the investments we are making to improve reliability and the customer experience. This can be seen in our customer satisfaction scores and in the recent JD Power electrical residential customer satisfaction ratings. BG and PECO and ComEd achieved top decile performance in customer satisfaction index. We improved or maintained our rankings in the JD Power rankings. Delmarva ranked first in the east mid-sized region, the first excellent utility to ever be ranked first. BG and PECO maintained their first quartile performance in the east large segment, and ComEd improved in its ranking to the second quartile. Generation performed well during the quarter. Nuclear produced 38.8 terawatt hours of zero emission electricity with a capacity factor of 95.1%. And excellent power and had a gas and hydro dispatch match of 99.7, exceeding our plan and the wind and solar capture on the plan was 96, was beat the plan of 96%. Now I'll turn it over to Joe.

Thank you, Chris, and good morning, everyone. Today I will cover our second quarter results, our quarterly financial updates, including trailing 12-month ROEs at the utilities, and our hedge disclosures. Turning to slide seven, we earned 50 cents per share on a gap basis and 60 cents per share on a non-gap basis, which is at the midpoint of our guidance range of 55 to 65 cents per share. Exxon utilities delivered a combined 39 cents per share net of holding company expenses. Utility earnings were modestly higher than our plan, largely due to O&M timing at ComEd, BG&E, and PECO, which will reverse itself over the course of the year. This was partially offset by milder weather than expected in the Philadelphia area, impacting PECO by about 1 cents per share. Exxon earned 21 cents per share behind our plan. This was a result of lower load volumes at Constellation due to mild weather and the extended outages at Salem. These factors were partially offset by favorable O&M, the strong performance of our generation fleet, and realized gains in our nuclear decommissioning trust funds. We are reaffirming our full-year guidance of $3 to $3.30 per share, and for the third quarter we are providing adjusted operating guidance, earnings guidance of $0.80 to $0.90 per share. On slide 8 we show a -over-quarter walk. The $0.60 per share in the second quarter of this year was $0.11 per share lower than the second quarter of 2018. Exxon utilities less hold co-earnings were up $0.40 per share compared with last year. The earnings growth is driven primarily by higher distribution rates associated with completed rate cases and higher transmission revenues at COMET and PHI relative to the second quarter of 2018. This was partially offset by unfavorable weather at PECO. Exxon's earnings were down $0.13 per share compared with last year. The decrease was driven by lower realized energy prices, partially offset by higher ZEC revenue from the increase in New York ZEC prices and the start of the New Jersey ZEC program. Moving to slide 9, our utility ROEs remain strong and we continue to exceed our 9 to 10% earned ROE targets across the utilities. The consolidated PHI utilities earned a .1% ROE for the trailing 12 months. Compared to last quarter, we had some help from the constructive distribution rate case settlements at ACE, PEPCO DC, and PEPCO Maryland offset by equity infusions across PHI. Legacy Exxon utilities maintained a strong .5% earned ROEs in the quarter. Importantly, consolidated ROEs across our utilities were 10.2%. We remain focused on meeting our utility earnings growth targets by maintaining the earned ROEs at PHI and sustaining strong performance at our other utilities. Turning to slide 10, on May 24th, BGE filed for a combined $148 million rate increase in electric and gas distribution revenues. The requested rate increase includes $81 million and almost $68 million for electric and gas revenues respectively, based on rate base of $5.4 billion and a requested ROE of 10.3%. The increase is primarily driven by the ongoing need for capital investments to maintain and modernize the electric and gas distribution system. It also reflects moving $15.8 million of revenues currently being recovered via the stride in electric liability investment surcharges into rate base. We expect to receive an order in the fourth quarter. On May 30th, PEPCO filed a multi-year plan in the District of Columbia requesting a revenue increase over three years to recover capital investments made during the 2018-19 period and planned investments over the 2020-22 time period. The request provides the necessary framework to allow PEPCO to align its system investments with policy goals set by the Commission and enable us to continue to make the investments needed to modernize the energy grid, support the District's energy goals, sustain first quarter reliability performance, and enhance programs and tools that have resulted in improved satisfaction among our customers. The multi-year plan includes five performance incentive mechanisms, or PIMs, focused on system reliability, customer service, and interconnection of distributed energy resources. The inclusion of these PIMs with the multi-year plan provide a performance-based rate-making approach designed to strengthen general incentives for good utility performance and penalize for underperformance. The multi-year plan provides customers with rate predictability and reduces the administrative costs to customers caused by frequent filing of traditional rate cases to recover costs. On July 9th, the Chief Public Utility Law Judge issued his proposed order in the PEPCO Maryland distribution rate case. The Chief Judge recommended a $10.3 million revenue increase and a .6% allowed ROE, which is 10 basis points higher than PEPCO Maryland's current ROE. A final order by the Maryland PSC is expected by August 13th. Finally, ComEd's annual formula rate update filing is expected to be decided in December of this year. More details on these rate cases can be found on slides 20 through 23 in the appendix. Turning to slide 11, we are continuing our robust capital deployment program at the PEPCO Maryland distribution rate. We have been able to take advantage of the favorable weather to fund investments in our gas business at BG&E, plus we had some additional storm-related work. As Chris mentioned, these investments are improving our infrastructure, increasing reliability, and helping to keep our gas industry running. We are also working on the development of our new gas pipeline. We are also working on the development of our new gas pipeline. We are also working on the development of our new gas pipeline. We are also working on the development of our new gas pipeline. We are also working on the development of our new gas pipeline. We are also working on the development of our new gas pipeline. Between the district's Department of Transportation and PEPCO focused on the underground placement of more vulnerable distribution power lines. Over the course of the initiative, up to 30 feeders will be placed underground with six during the first phase. The underground placement of these lines will make the electric distribution system more resilient during severe weather events, reducing the duration and frequency of electric outages. The second project featured is the expansion of Comet Itasca substation. This $48 million project installed a new distribution terminal and associated equipment, including an indoor switchgear building, three medium-power transformers, and 12 138 KV circuit breakers. The expanded substation provides capacity to power the equivalent of 45,000 homes. It will support three new data centers in the Itasca Elk Grove technology corridor near O'Hare Airport. These customers chose the greater Chicago area after several years of discussions with ComEd's economic development team, part of our continuing efforts to bring additional investment and jobs to Northern Illinois. On slide 12, we provide our gross margin update and current hedging strategy at the generation company. Before discussing the gross margin update, I'd want to spend a minute talking about the drop in the illiquid forward power curves during the second quarter, particularly in June. Prices in PJM in 2020 and 2021 declined sharply. Nighthub -the-clock power prices fell nearly $3 per megawatt hour for approximately 11% in 2020 and approximately $2.40 per megawatt hour or close to 10% in 2021. PJM Westumb prices fell more than $4 per megawatt hour and approximately 13 to 14% in 20 and 21 respectively. Jim can cover in more detail during Q&A, but at a high level, we think these declines reflected some combination of the following. Lower natural gas prices, a mild start to summer that weighed on prompt prices, which then cascaded out to the forward curve, which we have seen before. Some market anticipation of plants targeted for retirement looking less likely to retire, and hedging activity likely including market participants selling based on changes in the value of revenue put options sold or written to support new build power plants over the last few years driving down prices. Despite the mild weather and low price environment, 2019 total gross margin is flat to our last uptake. During the quarter, we executed $100 million in power new business and $50 million in non-power new business. We are highly hedged for the rest of the year and well balanced on our generation to load matching strategy. In 2020 and 21, our total gross margin is down $100 million and $250 million respectively. Open gross margin declined $550 million and $500 million respectively, primarily due to lower energy prices at PJM Westub, New York ZONE A, and PJM Nyhub. Mark to market of hedges were up $500 million and $300 million respectively as our hedge position mitigated part of the impact of the price decline. We also executed $50 million of power new business in both 2020 and 21. We continue to remain behind our radical hedging from perspective and added less than a radical amount of hedges across our regions during the quarter. We ended the quarter 10% to 13% behind radical in 2020 and 7% to 10% behind in 21 when considering cross commodity hedges. Our generation to load matching strategy remains a competitive advantage, contributing positive margin and providing a vehicle to bring our generation output to market in a disciplined manner. We remain comfortable with this strategy to hold open market length given the continued strength of our balance sheet. Finally, moving on to slide 13, we remain committed to maintaining a strong balance sheet in our investment grade credit ratings. Even at the June 30th pricing marks, given the levers we have available, we are confident that we will stay within our consolidated FFO debt metrics in our disclosure window of 2019 to 2022. Our consolidated corporate credit metrics remain above our targeted ranges and meaning roughly above S&P thresholds. Looking at XGen, we are well ahead of our debt to EBITDA target of three times. For 2019, we expect to be at two and a half times debt to EBITDA and two times on a recourse basis. With that, I will now turn the call back to Chris for his closing remarks.

Thanks, Joe. Turning to slide 14, we recognize the current power markets are creating headwinds for us. We're prepared to meet them head on and take thorough or thoughtful action if necessary. In the meantime, we are accomplishing the things we committed to do, including maintaining industry-leading operations, meeting our financial commitments, effectively deploying more than $5 billion in capital across our utilities this year, and advocating for policies that support clean energy. Our strategy remains the right one, and we are committed to our value proposition. We continue to grow the utilities, targeting a .8% rate-based growth and a 6% to 8% earnings growth through 2022. We continue to use free cash flow from the GENCO to fund the incremental equity needs of the utilities, pay down debt, and fund part of the growing dividend. We will continue to optimize the value of X-Gen business by seeking fair compensation for our zero-admitting generation fleet, closing uneconomic plans like we're doing with TMI, and selling assets where it makes sense to accelerating our debt reduction plans, and maximizing value through the Generation to Load Match Strategy constellation. We will sustain strong investment-grade credit metrics, and we will grow our dividend annually 5% through 2020. The strategy underpinning this value proposition is effective. We remain committed to optimizing the value of our businesses and earning your ongoing support of Exelon. Operator, we can now open the call up to questions.

Thank you. I'd like to remind everyone, in order to ask a question via phone, please press star then the number one on your telephone keypad. Your first question comes from the line of Greg Gordon of Evercore ICI.

Hey, good morning. Hey Greg. So one high-level question and then maybe one or two in the weeds questions. And I don't want to ask you anything that you're maybe not comfortable delving too deeply into, but I'm going to anyway. You know, you mentioned the concept of levers that you have in order to stay, you know, on track to generate the free cash flow and credit metric targets that you laid out for us at the beginning of the year despite the fall in the forward curves. And you talked about how you won't run power plants that aren't cash flow positive. And look, I've covered the stock for a long time, covered the company for a long time, we've been in this situation before and nothing is ever as good or as bad as it looks in the moment. But can you tell us, should this persist, what some of those options are in a little bit more detail, please?

Yeah, I'll let Joe go through the list of what we've got laid out right now. We've been talking quite a bit about it, meeting on it as we watch the market. So Joe.

Yeah. Good morning, Greg. Greg, you mentioned one of them. I think we've proven through our time with our financial discipline that we're not going to run power plants in perpetuity that are uneconomic. So that would be the first lever. Obviously, you've seen us continue to drive efficiencies in our business and continue to look at ways to streamline our costs. And we would continue to do that. And that would be across our Exxon Generation business as well as at the business services company. At our disposal, and I won't speculate on what at this time, but we obviously have the opportunity if necessary to look at asset sales. We do have a small amount of growth capital in our Exxon Business. We would look at that and take a hard look at that. And then there are alternate forms of financing when you think about project financing and other things. So I think when you look at it, this is a point in time estimate of our financials. As you said, we've seen the markets move up and down. We're comfortable, like I said, with our credit metrics through the disclosure period. And we continue to allocate capital in the ways we've laid out. And if we had to discontinue, we would look at these levers.

Yeah, I'm very cognizant that some of those plants are large nuclear units in the state of Illinois. And I'm also cognizant that you're having a dialogue with legislators and other constituencies in the state around an omnibus energy strategy that takes into account and contemplates certain actions with regard to those plants. Can you tell us how broad that coalition is as we get into the veto session and whether you think that the state policymakers understand the implications of the lack of necessary market reforms in PJM and the need to take back control of the market?

As you can imagine, we have a significant communications drive with the legislative and the administration on the situation. And we are prepared to present them with the coalition, I'll let Kathleen describe who she's working with, that will balance out the needs for the state, the goals that the governor set after his election to get to 100% clean by 2030 and be able to do that in an economic way that does not harm our customers. Do you want to talk about the coalition?

Yeah, and good morning, Greg. There are a number of stakeholders that are very focused on getting clean energy legislation enacted in Illinois. As you know, a number of states across the country have already set 100% clean energy targets. And it's not just states like California and New York, it's across the country. And so Illinois, there's a lot of emphasis on making sure that Illinois, which is already the cleanest state in the country, has an equally aggressive target. So on that question, we have folks in the environmental community heavily focusing on environmental justice players, the renewable developers are very focused on addressing both flaws in the prior version of the state's clean energy targets to make sure that they can achieve the goals that have been set previously, but also, as I said, set a more ambitious new target for renewable development in the state. The consumer advocate is heavily focused on this policy as well because the question of states having to pay twice for capacity is very much in the forefront and ensuring that if we're going to incentivize clean energy, we can count that capacity towards our obligations with BJM. And then finally, the labor community is very focused on what these policies mean both for new construction and preservation of existing clean energy resources. So that's the coalition that's focusing on putting the package together. There are a number of parties who will come together in the end to help communicate the message that Chris mentioned that this is important for the state, but it's not going to be possible if we can't allow those resources to count as capacity, and that's why the FRRP is foundational to getting this policy done.

Thanks. And my final question was actually a numbers question on the update on the market to market, Joe. There was a $50 million decline in power in new business to go. Is that because that moved into hedges because you executed sales or are you assuming either lower volumes or lower margins in the out years in the retail business?

Hi, Greg. Yeah, this is Jim McHugh. That is just executed. That's executed business that now has moved into the market to market of hedges. When you net that all together, the numbers, those two lines would be flat from last quarter. It's just executed now.

Okay. Thank you.

Thank you. Your next question comes from the line of Steve Fleischmann of Wolf Research. Your line is open.

Yeah, thanks. I've got follow-ups to both of Greg's questions. So first of all, I know in the past when prices have fallen a lot, at certain times you've talked about actually how much money losing plants there are and potential offsets. Can you give any flavor on that on just, hey, if prices stay this low, if we shut certain plants or generally shut plants, what the potential offset could be?

If you're asking in market prices, we don't calculate the effect of uneconomic plants being shut down on the effect of the market. If you're asking about the effect of removing the negative free cash flow, we haven't got those numbers to be published right now. It's something that we're looking at, but we're trying to evaluate them unit by unit and then in aggregate. As we've said publicly, right now you can see a challenge in the future if this market persists between the capacity and the energy market that Dresden, Byron, and Braywood are financially challenged. Now, we do think we've got a clear path with good coalition to support fixing that at some of it at the state level and we still are working very hard with PJM for FERC to continue on base load scarcity and the capacity market reforms that should correct and make a fair market. Short of those things happening, those three sites, you can look into the future and see the challenges that they have.

I guess the point there is if we're just using current forwards and taking it down, we're including losses on plants that you would not just sit and take forever.

Either

we

have a clear path to securing them or the units will be shut down. We will not damage the balance sheet sitting around for years with negative free cash flow or negative earnings.

Okay. Then just specific question to the Illinois coalition, can you just give any color, if possible, that since this news from a few weeks ago came out about the subpoena, has there been any, have these talks continued and is there any kind of public process we'll be able to see kind of those talks or is it just going to kind of be suddenly a legislative proposal?

Steve, it's Bill Van Haney and the activity that has started and continued for a number of months on advancing the clean energy legislation among the coalition that was referenced by Kathleen and by Chris remains unchanged. We're meeting regularly. We're doing the stakeholder outreach. We're trying to craft a package and educate members of the legislature and the dependency of the grand jury subpoenas had no impact on the level activity or the intensity of the activity in that regard.

Okay. Thank you.

Your next question comes from the line of Chris Turner of JP Morgan. Your line is open.

Good morning. I was wondering if you could just help us with some background of your franchise agreement in Chicago kind of when that expires, the terms of renewal, et cetera, and kind of how you're thinking about that right now.

Well, I'll start. Hi, this is Anne and Joe Dominguez is here as well. But basically the expiration date is the end of December of 2020. The city needs to give us an indication by the end of the year as to whether they want maintain status quo, renegotiate, or terminate the franchise agreement. So we'll know by the end of the year. But we're in discussions with them. We've started to have discussions around that. We understand what their priorities are and their, I think, priorities are very much aligned with ours. They want to see more clean energy in the city of Chicago and they're concerned about vulnerable populations in particular in terms of pricing. Those are both strong strategic elements of our focus going forward at all our utilities. But that's the status right now.

Just to supplement what Anne said, we've been in the process of these negotiations for some time. We've exchanged terms and had detailed discussions about how the agreement would be structured going forward. We had a slowdown in those negotiations during the transition to the new mayor. But those negotiations have resumed in full at this point.

Okay. And right now that is your set of assets and you would need to be compensated if anything changed there.

That's correct. But again, the focus here is on getting the franchise agreement done. Our expectation is it will be fully negotiated and done. We'll address the issues that Anne talked about to the extent municipalization has looked at. That will come with a very hefty price tag as you know. And I don't think realistically that's a path we're going to go down.

Okay. And then I guess just more modeling here for the balance of 2019. You put out the third quarter guidance there which was I think a little bit less than we had expected. How are you thinking about the fourth quarter right now and what I guess might look like a headwind at least in the back half overall?

You heard me say in my prepared remarks that we reaffirmed our guidance in a range of 3 to 330. That's inclusive of the earnings guidance we gave you obviously for the third quarter and we're comfortable with those numbers.

Okay. Anything to think about that might be kind of one time or nonrecurring in nature for the third or fourth quarter that could help you year over year?

I mean you saw some of the drivers of the second quarter when we talked about the lower load volumes at Constellation driven by the unfavorable weather and we continue to as Jim just talked about we continue to execute our new business at Constellation and we continue to manage the utility business accordingly and we're comfortable with the full year guidance.

Okay. Great. Thanks Joe.

Your next question comes from the line of Michael Weinstein from Credit Suisse. Your line is open.

Hi guys. Just one quick follow up on guidance. The guidance for 4.2 billion of cash flow generation from ExGen over the next four years, what does that assume in terms of uneconomic plans that might be operating or I guess retirements going forward of those types of plans? What's built into that 4.2 billion number?

Good morning Michael. It's Joe. As Chris mentioned when he just said inclusive when you look at the three plants in Illinois that he mentioned Byron, Gravewood and Dresden those plants are running in those cash flow forecasts and to the extent these power prices continue there's obviously challenges financially with those and as I said in my remarks we won't continue to run those plants in perpetuity uneconomically. Having said that we haven't provided the numbers specifically but we will you know we put out a forecast on our fourth quarter call for 7.8 billion dollars of free cash flow from 2019 to 2022 coming off generation that we're still working with that number.

So I mean would it be accurate to say that there's upside either way from this point at this point with the forward curves where they are?

You know we give you an update at the end at our fourth quarter call and it's you're getting like one side of the story here obviously because we in the numbers we provide we're showing you the mark to market you see our gross margin disclosures and the change quarter over quarter driven this quarter driven by the price drops we saw in the second quarter. I also discussed there are other levers at our disposal those aren't reflected in our disclosures but we can go back to what we modeled on the fourth quarter call and that's what we've disclosed at this point.

Okay great thanks.

Your last question comes from the line of Truffle Meta of Citigroup your line is open.

Thanks so much hi guys. So maybe just following up a little bit on the power markets it was very helpful to get the levers that you've talked about but just to understand from a PJM perspective do you see more happening on the market side as in other players shutting down other plants or other form of rationalization like you've also talked about regulation where do you see PJM going because if it stays this way clearly it's unsustainable so wanted to understand how you thought the market would play out.

Yeah okay Truffle this is Jimmy I'll start I think from a market perspective first of all the one thing we I want to highlight to Joe's point about this is a point in time we've already seen the NiHub market move up a dollar on the forward curve since the end of the quarter and the West Hub markets moved up about 75 cents since the June 30th pricing so we've seen a pick up in prices so far I think when it comes to what we're working on we've talked over the last several quarters on the market reform side fast start pricing is waiting to be enacting enacted there's some work being done on on reserves and scarcity pricing and the ORDC curve in PJM and then in the long run it's it's a little bit lower priority right now for PJM but the focus on the base load price formation and integer relaxation those are some of the things I think there are we have new builds and retirements both happening over the next four or five years as natural course of business in our fundamental analysis so there will be a little bit of that but I think by and large the reforms are around price formation and then in the long run you know if if we're able to come up with a market solution to have carbon pricing in the market would be another thing in the long run that would be something we would all continue working on the one thing that's interesting to me about where we've seen these prices in that 22 dollar area in the NiHub if you look out at Cal 21 Cal 22 Cal 23 you know that's trading down where the quarter two just cleared quarter two NiHub just cleared 22.25 cents with very very mild weather so the entire curve is is trading where a very mild quarter just traded so it's an interesting note to me and I think gives us some insight into why we think those prices on the forward curve to have that have already responded slightly higher in the last couple weeks

that's super helpful color and maybe just one follow-up more strategic if you do see these profiles does that mean that you think more retail would be helpful to the business do you do you look to expand on the retail side or maybe acquire more retail businesses is that something that you think would work

yes so I think from a retail perspective our our customer faces facing businesses are doing pretty well the margins are hanging in win rates are strong and we're holding our market share our retail customer facing business and our wholesale load auctions and wholesale origination businesses have performed well I think as far as acquisitions and expanding it we have a we've talked for a while now about having grown really what is the best in class platform so if we we will look to acquire books of business if there's a value proposition there that we can absorb it into our best in class platform and just take our book of business we'll look for those opportunities and and we we certainly would take a hard look at them

all right really helpful thank you guys

I would like to turn the call over back to speaker Chris Crane please go ahead sir

thank you all for participating in call today we remain on track to meet our commitments to our customers communities and shareholders with that we'll close up the call

this concludes today's conference call you may now all disconnect