Greetings and welcome to the FirstEnergy Corp. Second Quarter 2012 Earnings 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.

Thank you, Latonya, and good afternoon. During this conference call, we will make various forward-looking statements within the meaning of the Safe Harbor provisions of the United States Private Securities Litigation Reform Act of 1995. Investors are cautioned that such forward-looking statements with respect to revenues, earnings, performance, strategies, prospects, and other aspects of the business of FirstEnergy Corp. are based on current expectations that are subject to risks and uncertainties. A number of factors could cause actual results or outcomes to differ materially from those indicated by such forward-looking statements. Please read the Safe Harbor statement contained in the Consolidated Report to the Financial Community, which was released earlier today and is also available on our website under the Earnings Release link. Reconciliations to GAAP for the non-GAAP earnings measures we will be referring to today are also contained in that report as well as on the Investor Information section on our website at www.FirstEnergyCorp.com/ir. Participating in today’s call are Tony Alexander, President and Chief Executive Officer; Mark Clark, Executive Vice President and Chief Financial Officer; Leila Vespoli, Executive Vice President and General Counsel; Donny Schneider, President of FirstEnergy Solutions; Jim Pearson, Senior Vice President and Treasurer; and Harvey Wagner, Vice President, Controller and Chief Accounting Officer. I will now turn the call over to Tony.

Thanks Irene and good afternoon, everyone. Thank you for joining us. Today, I’ll provide an update on our plant and retail operations, regulatory matters and the impact of recent storms. I’ll finish with a discussion of our non-GAAP earnings guidance, and then Mark will talk about our earnings drivers and provide the detail on our second quarter results. Let’s get started with an update on our generating units. As mentioned on previous occasions, we’ve been rigorously evaluating the environmental controls that will be needed to meet the new environmental regulations including the Mercury and Air Toxics Standards rule or MATS that is scheduled to go into effect in 2015. As a result of this analysis, we have significantly reduced our projected capital investment related to MATS compliance. We now estimate investment of about $975 million across our Fossil Fleet. This is down from the $1.3 billion to $1.7 billion estimate we provided in February and well below our initial projections of $2 billion to $3 billion. While we still have work to do to confirm and refine our current estimate, we’re clearly moving in the right direction. At the same time, we’re moving forward with our previously announced plan to deactivate units at seven of our older coal-fired plants by September 1st of this year. Again, as a result of the MATS and other environmental rules, the effective units are Eastlake 4 and 5, Bay Shore 2, 3 and 4 and the Armstrong or R. Paul Smith, Albright, Willow Island and Rivesville plants. We expect to continue operating Eastlake 1 through 3, Lakeshore and Ashtabula until early 2015 coinciding with the conclusion of reliability must run or RMR arrangements with the PJM interconnection. We filed with FERC regarding RMR compensation for these units in July. As you recall, we also…

Thanks, Tony, and good afternoon everyone. As Tony mentioned, I’ll start with the review of second quarter results then I’ll provide an update on the continued success of our retail strategy and finally I’ll conclude with several comments on next year’s forecast. Before I move on to the details of our second quarter results, I’ll take this opportunity to remind you of several housekeeping items. First, this is the first quarter we’re presenting our total company results in a combined year-over-year format, fully reflecting our merger with Allegheny Energy. Second, as we did last quarter, we are normalizing the revenues, expenses and output related to the deactivation of our older coal-fired units. And finally, with the integration of Allegheny into our automated financial reporting systems in the second quarter, we’ve modified our regulated reporting segments to isolate all federally regulated transmission operations and state regulated distribution operations as separate segments. Looking now at second quarter results excluding special items, non-GAAP earnings were $0.60 per share compared to $0.70 per share in the second quarter of 2011. On a GAAP basis, this quarter’s earnings were $0.45 per share compared to $0.48 per share in the same period last year. As we move to the detailed review of second quarter 2012 drivers, it may be helpful for you to refer to the Consolidated Report to the Financial Community that was posted on our website this morning. Special items for the second quarter are detailed on page four of the report. These items have a net impact of decreasing GAAP earnings by $0.15 per share. By comparison, in the second quarter of 2011, special items reduced GAAP earnings by $0.22 per share. Looking at the special items for the second quarter of 2012, a gain of $0.01 per share related to the impact…

Thank you. We will now be conducting a question-and-answer session. (Operator Instructions) Our first question comes from Dan Eggers with Credit Suisse. Please proceed with your question. Dan Eggers – Credit Suisse: Hey good afternoon guys.

Hi Dan.

Hello Dan. Dan Eggers – Credit Suisse: Hey, just on the 2013 number, Mark, I take it as you guys are withdrawing the 2013 guidance number or is this the number you’re keeping but there is you have certainly a number of issues at play that could affect it that we will have to kind of wait and see how they play out for the rest of the year?

That’s a good question Dan. I think the answer to next year’s forecast is both simple and straightforward. There’ve been a number of substantial changes that will affect next year’s forecast. As I said, some are going to be positive, some are negative, and some we just don’t know yet. What I do know is that I’m working with a pretty long list of changes, I mentioned the Ohio – approving the Ohio ESP, extending October-January auctions, storm costs, the New Jersey case, coal transportation, power prices, transmission whether we can accelerate, of course, the big gorilla in the room being the general economy, but let me just address two to give a little bit better flavor. Our earlier forecast assumed a one-year auction in October and January, while we believe the changes Tony mentioned the three years will help the consumer it will also help FES. Another example was the AEP ESP and as Tony again said we think that’s very positive for the consumer depending on how the commission rules that could be very positive for FES. And, as you just said the point we’re making is that we need to update a long list of items, which we plan to do along with our normal fall budgeting process. I apologize if that’s a long answer, but it’s a long list of changes that we have to get updated and that’s what we’re trying to do. Dan Eggers – Credit Suisse: Okay, I think I got it. Thank you. And then Tony I guess just, can you share some thoughts kind of out of the RPM auction results and kind of where the pricing went with the big demand, response, consumption in ATSI. How important do you think it is to get a more of a physical resource in that market in the future and your kind of your comfort around reliability in the region as we look forward?

Sure Dan, I think demand response when it comes in across a broad region and is not clearly identified in a particular area has some benefit, but it’s not the real type of benefit that you’re looking for in what otherwise are fairly constrained areas. My sense is we’re going to have to get a better handle on that to determine whether or not it’s usable or it’s just an interesting thing to have, but it will not improve reliability in and around the area. My own sense is that many of the transmission projects including the conversion of the generating units in the – in and around Cleveland to synchronous condensers will put us in a position to deliver reliable electric service in that area. It’s going to take some time to put all that in place and that’s why we have the RMR arrangements being contemplated, but we intend to work as aggressively as we can to meet the schedule and to be able to stay within the guide post that we’ve kind of laid out for ourselves and that is basically to not be in a position to be running any of our power plants beyond March of 2015 that we’ve otherwise scheduled to shut down. Dan Eggers – Credit Suisse: Okay. And I guess just one last one. As you look at kind of the mix and the retail business or kind of the gain in customer count relative to where your projections were at the Analyst Day, it looks like there might be a little behind on some of the share gains and LCI, MCI maybe relative to plan. Where do you guys think you are in capturing the new customers over the course of the schedule and it was always kind of an assumption that you have an acceleration in the second half of more the government ag activities?

Well I think we knew that once our retail group went the government aggregation it was just going to be a question of how fast you can get them transitioned over which as you said was mostly in the second half. I think we’ve had great success in the large commercial, medium-sized commercial, I think we are a little behind in the mass market, but I know they’ve got some good plans to catch back up there. So, Dan I get a weekly report in terms of what we win and what we lose and we’re up for the year across all the different segments particularly in southern Ohio. Dan Eggers – Credit Suisse: Okay. Thank you guys.

Our next question comes from Julien Dumoulin-Smith from UBS. Please proceed with your question. Julien Dumoulin-Smith – UBS: Hey, good afternoon guys.

Hi Julien. Julien Dumoulin-Smith – UBS: So first kind of following up on Dan’s first question there. If you could provide a sense of priorities or rather impacts if you will, you listed out those few items, which of those are most impactful and it seems as if a lot of those are actually positive items to 2013 EPS as you think about the update. So, if you were to kind of ballpark it, is this actually a revision downwards or upwards? I apologize if that’s an obvious question.

I think it’s an obvious question but we don’t have an obvious answer. We just have to get through a long list. I think as we said earlier, the retail group is 70% closed right now for 2013, so power prices are going to impact them. I don’t know what’s going to happen with the economy, the election, taxes, budget, things like that. Power prices are not a positive, depends on whether the commission rules favorably this week, that could be a positive. One big positive potentially is we’ve reduced the amount of spend on MATS from $1 billion to – down $1 billion to $2 billion. We’ve got transmission spend, how much transmission spend can we accelerate into 2012 that’ll affect 2013. So I don’t know if I would characterize any one weighing more than the other. I think we’ve got to get our book closed for 2013. We’ve got to see what power prices are doing, how much more channel switching Donny’s group in retail can do. So as I said, there are some really strong positives. Power prices are not going to necessarily be a positive and we’ve got to wait for some regulatory outcome and of course a big potential positive would be the auction, since they are now into three years. So good question, I just have a long list of things that we have to get updated, plus as I said before, this is really the time of the year we are doing our normal budgeting process. So we’ve got to get just the normal budgeting updates incorporated. Julien Dumoulin-Smith – UBS: All right. Thank you. Maybe a follow-up again kind of to Dan’s original set of questions here on ATSI, as we look forward and as we’ve seen your transmission spend announced in the quarter, how are you guys thinking about, not to jump the gun here, but the 2016, 2017 auction in the ATSI zone and any kind of commentary I imagine, or at least I understand that the transmission is set to go into service prior to the next auction date?

Well, Julien, some of it will, some of it will be perhaps beyond that. The real issue I see in terms of being able to get many of those transmission facilities in place, will not necessarily be driven by the construction schedule, but will be more affected by our ability to acquire rights of way, abilities to get outside crews in to support it, and doing that and getting the permits necessary to complete that amount of work in the timeframe that we’ve laid out in front of us. So, we have some work to do, there’s a lot involved in the process, we’re in the early stages now, we’re preparing environmental impact statements and all of the other parts, pieces and parts that will require regulatory approval, primarily from siting organizations, and as we move in that timeframe, we’ll be better able to predict when we will have the particular parts of those projects in place. Because this is not just one project, there are a number of things that are going to be done. Substations are going to be enhanced, additional ones are going to be built, new lines are going to be brought in to serve those. The synchronous condensers will be put in place. We’ll have to see how all of those impact the schedule that we have now as well as what the loads do in the Cleveland area between now and 2016 and 2017. Julien Dumoulin-Smith – UBS: Great. Thank you for the clarity.

Our next question comes from Gregg Orrill with Barclays. Please proceed with your question. Gregg Orrill – Barclays: Thanks a lot. I was wondering if you could talk a little bit more about the Ohio ESP approval and the provision where they changed the POLR auctions to three years versus one and just whether you feel that is more attractive from a FirstEnergy Solutions standpoint? And if you’d be more interested in participating in those auctions?

Let me address that one first. The primary purpose of this is providing a more gradual glide path for our customers, so that we could take out the volatility that we otherwise would have anticipated happening between today’s pricing, which are based on very low capacity costs in the main, and what we are seeing in the 2014, 2015, 2016 kind of timeframe. We thought smoothing which is kind of consistent with what our utilities have tried to do for as long as I’ve been actively involved in trying to work through what otherwise are potential spikes in pricing, try to blend that out. From an FES strategy standpoint, whatever that auction is – it is, our strategy continues to be focused on direct sales to individual customers pulling away from POLR obligations and POLR sales, because we believe that’s the greatest opportunity for this company to be successful over the long term. We will likely participate in auctions and we do in multiple regions and will likely also participate in these auctions, but again, much of that will depend on where is the status of our retail book of direct sales and how much we have available or do we want to place in that kind of call auction associated with a POLR transaction. Gregg Orrill – Barclays: Thanks, Tony.

Our next question comes from Ashar Khan with Visium. Please proceed with your question. Ashar Khan – Visium: Good afternoon.

Hi, Ashar. Ashar Khan – Visium: Can I just ask when should we hear back on the new guidance? Is it end of the year? Next year? Or could you give us a timeframe?

That’s a good question. No, not really. I think we got to get through the whole process as it’s a long list, got to get through our normal budget process. I think our Investor Relations folks told us that there is an Analyst Meeting early in 2013, so it can’t be any later than that and if we get it done sooner we’ll get it done sooner. So, it’s just a lot of work we’ve got to get done between now and then. Ashar Khan – Visium: Okay, okay. And then could you just again, I’m sorry to apologize for getting it repeated could you just go over the factors again the changing factors? Could you just repeat them if you don’t mind?

Well these are just some of the ones off the top of my head that I put down, it’s the approval of the Ohio ESP. Ashar Khan – Visium: Okay.

The auction that’s been extended from one year to three years in Ohio for both October and January. Ashar Khan – Visium: Okay. So that’s a positive, right?

Right. The storm costs and the request to defer those that Tony mentioned in his text in West Virginia. We’ve got the New Jersey rate case. All the plant deactivations that’s going to affect our coal and transportation costs and those are all being negotiated by FES right now. Our power prices are going to affect the open position, where FES is 70% closed. I think the last time we spoke was somewhere around 50%, 55% something in that range. So they’re right on their glide path and right where they need to be. I spoke about transmission reliability investments, the fact that we don’t have some of these big capital cost related to MATS, related to the peakers, the $500 million there. How much our transmission group can get accelerated on the transmission side both into 2012 into 2013. Then the big gorilla in the room is the economy, where the economy is going, what’s going to happen with the tax cliff, are they going to extend it, not extend it. So, those are just some of the things that I wrote down really quickly off the top of my head, but I can assure you that the list is three to four times that length. Ashar Khan – Visium: Okay. And then can I just Mark, just from our purposes, I have not forget I don’t have the presentation in front of me. What had you assumed for the economy for 2013 in terms of growth?

I think in the distribution side, Jim do you know that – probably like 1.5%?

About 1% to 1.5%.

1% to 1.5% on the distribution side, but it doesn’t necessarily affect what the retail group is doing. They’re targeting a set number of megawatt hours at the highest possible margin. So, if the economy is going backwards or forwards, doesn’t really matter to us because at the retail side, they’re targeting a set number of megawatt hours which I think in 2013 is 112 as opposed to 104 in 2012. So, they target megawatt hours, the distribution models and forecasts around the economy, which is I said is somewhere between 1% and 1.5%.

But the economy impacts – the amount available to go after in the market. So, they are integrally tied as to whether or not this economy is going to get back in growing or whether or not we’re going to stay stagnant in 2007 levels. When in fact at the end of the day, we had assumed that this economy was going to get a little bit back on track, it clearly has not yet, and it is impacting the estimates. Ashar Khan – Visium: Okay. That’s great. Thank you so much

Our next question comes from Stephen Byrd with Morgan Stanley. Please proceed with your question. Stephen Byrd – Morgan Stanley: Good afternoon.

Hi, Steven.

Hi, Steven. Stephen Byrd – Morgan Stanley: Wonder if you could talk a bit about the trends you’re seeing in competition levels on the retail side. Mark, you mentioned margins they were down just a fairly modest $1 megawatt hour whereas wholesale prices fell significantly more, is this in line with your expectations, are you seeing certain emerging trends with respect to the degree of competition?

Actually, I have Donny Schneider he’s the President of the Retail Group. So, I’m just going to let Donny speak for his group.

Stephen, clearly the competition is out there. I think we’re doing a great job. One of the things that we monitor very closely is what we call our attrition rates and so these are customers that we’ve traditionally held and whether or not we’re able to retain those. And in our residential space, when you look across our EDCs we’re 3% to 4% year-to-date attrition in our FE Ohio, that’s more like 1%. So we’re doing very well at being able to retain those customers. In other EDCs where we call them our close to home EDCs, where we go after customers, we’re doing quite well across the board in being able to secure market share that we’d anticipated. Stephen Byrd – Morgan Stanley: Okay, great. Thank you. And just as shifting gears over to PJM, there have been a number of conversations about the minimum offer price rule and that there is continued discussions about potential modification for that. I was just curious from your perspective how that process has been unfolding, anything just out of the ordinary as you’ve been going though that, is it proceeding as you would hope. How do you see that shaping up in terms of potential changes to the MOPR?

Stephen, this is Donny again. Yeah my folks are involved with that. As you know PJM has a very elongated process when it comes to these things. So they’re actively involved. I think it’s a little soon to tell, to speculate on how that might come out. So we’re just going to have to watch it. Obviously it’s something we’re very interested in and we’re paying close attention to that, but a little soon in the process to speculate. Stephen Byrd – Morgan Stanley: Understood. Thanks Donny.

Our next question comes from Paul Patterson with Glenrock Associates. Please proceed with your question. Paul Patterson – Glenrock Associates: Good morning.

Good morning Paul.

Hey Paul. Paul Patterson – Glenrock Associates: I’m sorry. The AEP ESP it sounds like you guys thought that that might turn out positively for you. Is that I mean just wondering what you’re thinking is in terms of what’s going to be coming out there? And whether or not this capacity ruling was – how that figures in your thinking and also I guess remarks by Duke that they might be looking at this – the face that they’re an FR entity and therefore they might be able to get a capacity cost. They’re at least looking into that sort of issue. Any thoughts there you want to just elaborate a little bit on?

, this is Leila Vespoli. I think the capacity order that came out was very favorable. They did defer one issue to AEP’s ESP and that was how they were going to handle the deferral between the 188 and RPM. So, we’re still looking to see and I guess that would be tomorrow when the commission issues its order in the APKs and hopefully we’ll get that result positively, and then and kind of have a complete picture with respect to that. With respect to...

Duke.

Duke, yeah. I apologize, I forgot the second part of the question. With respect to Duke, yes, they have raised issues with respect to that. If you think about how AEP presented their case, they presented a cost-based case and that’s what the commission was looking at. So, in setting AEP’s state based FRR mechanism, they looked at cost. So, if Duke is thinking of trying to implement something like that, from our standpoint they have an ESP that’s in place that incorporated RPM pricing.

Duke, per day, DPL Go ahead, keep going.

And so with respect to that I think that they would have a huge hurdle to clear with respect to that. Paul Patterson – Glenrock Associates: Okay. And then with respect to peak demand just in the third quarter here we’ve seen a lot of hot weather in the Midwest and we haven’t seen – and in the East Coast, and we haven’t really seen much in terms of high peaks at PJM, and I was just wondering if you could maybe sort of give us an indication as to what you’re seeing on the demand response side, are you seeing demand response in the energy market which has been sort of a tariff that PJM has put in here, or any sort of comments you’d like to make on that?

This is Donny. I think Mark touched on the residential space being down a little bit, what we’re seeing is that for a given number of residential customers, if you assume an EDC where the residential customer count has not changed, the actual consumption is down a little bit, with what we’d normally expect to see with these hot conditions. So, it looks like the economy, the energy efficiency, et cetera is starting to have a bit of a dampening effect on residential consumption. Paul Patterson – Glenrock Associates: Okay. And then just finally on, Ashar asked about economic forecast, and as opposed to sort of a sales growth, I was just wondering sort of a GDP forecast, what have you guys been assuming for 2013 just in terms of the economic rebound?

2.5%, but that really could get changed depending on what happens with the tax cliff. Paul, I don’t know what that number is, but I have seen numbers like 3% to 5%, if they don’t extend it. You subtract that from anything and it’s not pretty – so but we assumed about 2.5%. Paul Patterson – Glenrock Associates: Okay. Thanks a lot.

Our next question comes from Paul Ridzon with KeyBanc. Please proceed with your question. Paul Ridzon – KeyBanc: With regards to your CapEx around environmental, it’s come down pretty considerably. Where have you found that opportunity?

I think pretty much across the board, I think Tony challenged the folks to come up with creative solutions and they’ve done that. I think coal firing with gas is going to help if the power prices stay low. There is some things we can put off, moving some of the outages around, it’s pretty much across the board. We’re pretty pleased with where they are, but we keep pushing them to lower that number too. So Tony you want to...

No, I think it’s just a comprehensive look at each and every unit and each and every plant. And looking more holistically at the plant and its capabilities and what you can do with existing equipment to enhance it and improve it, for example the prove performance of precipitators or tightening up so that you don’t have as many air leaks, a whole series of things unit by unit specific to eliminate kind of the large, bigger ticket items that would otherwise be kind of hung on the back end of the plant because you’re not making the rest of the facility as efficient and as effective as it can be. Paul Ridzon – KeyBanc: One of the items you mentioned, Mark, around the uncertainty over the 2013 power prices, but you took your open position from 45% to 30% and as you close that 15% how is that pricing relative to what your view was when you did have guidance out there?

It’s lower. I don’t know, Donny, you want to speak to...

Yeah I think, in the first quarter of this year, first and second quarter we saw a dropoff of about $10 a megawatt hour in wholesale prices. Paul Ridzon – KeyBanc: Okay. Thank you very much.

Our next question comes from Hugh Wynne with Sanford Bernstein. Please proceed with your question. Hugh Wynne – Sanford Bernstein: You all have talked about the offsetting impacts of rising contract sale volumes against the decline in capacity prices and energy prices. There has also been a material mix shift in the composition of your contract sales from POLR to large C&I. And I was wondering if you could comment year-over-year whether the mix-shift has been positive or negative to your commodity margin, or broadly neutral?

Hi, Hugh. This is Donny. I would say it’s been very positive. And I’ll just use FE Ohio as my example. If you think about when FE Ohio first opened up, and I’m using FE Ohio as an example; I could use any one of the EDCs as they progress from the beginning to where they are sometime later. FE Ohio opened up in the spring of 2009. When it first opened up, there was very little shopping and so as you went in there and procured tranches, if you were a participant in POLR, you were receiving a nice margin and a nice volume. As time has went on though, that volume has absolutely crept away from those POLR providers. Today in FE Ohio, you’re probably somewhere in the neighborhood of about 80% of the customers have now shopped. So, if you had only participated in that POLR procurement, not only looking now at 2012 – not only would your rate have dropped off substantially but more importantly your volume would have been completely or, not completely but 86%, 80% erased from where you were just three short years ago. So our move from POLR to the LCI, MCI, Gov Agg, et cetera has allowed us to secure that volume.

Hugh, this is Mark. I would add one additional caveat to what Donny just said, one of the things that we’re working very diligently on and have a lot of algorithms on is, suppose you can move a customer megawatt hours between channels or inside a channel, you’ve got an LCI customer that’s served by one EDC, can you move those megawatt hours over to another EDC in the same channel, but a higher margin or even within the EDC? And one of the big issues that comes up in the large industrial market is can we take those megawatt hours and move them to any of the other channels like mass market or something else? So they spend a lot of time trying to move either within channels or out of channels to increase the margin. Hugh Wynne – Sanford Bernstein: Right, okay. And if I could just ask a follow-up question regarding the radical reduction in your MATS CapEx, is the coal firing with gas likely to be accompanied by a reduction in the variable cost of running the units that coal fire, or given forward prices for coal and gas an increase in variable cost? And I guess if it’s the latter, is it material?

Yeah, a lot of that is going – Hugh, this is Tony. A lot of that is going to depend on the price of natural gas obviously and the relative price nat and coal. We’re looking at it more from an operational standpoint. It’s not going to have some flexibility, but you also have to include all the back-end costs where you are not going to dispose of as much material so and you are not going to need as much material going in to your scrubber systems because you are not having to deal with as much of the effluent. If the coal kind of a relative balance, my sense is it is going to be about neutral. With respect to the overall cost, it could be sometimes plus, it could be sometimes a little negative. Hugh Wynne – Sanford Bernstein: Well, hats off to your engineers, that’s a pretty impressive savings.

Thanks a lot.

Thanks. Operator, how about we take one more question?

Okay. Our last question will be from Andy Levi with Avon Capital. Please proceed with your question. Andrew Levi – Avon Capital: Hi guys, how are you?

Great, Andy. Andrew Levi – Avon Capital: Just want to try to clarify something. Obviously, you guys know what you’re doing as far as 2013 and you’ve articulated very clearly that there are numerous moving parts. At the same time obviously by kind of talking the way that you guys have, it has caused some angst in your stock today. And so I just want to give you kind of one more chance to kind of come out and just try to make a little bit clearer whether we should be concerned that there could be a significant revision down to 2013 estimate? I mean although it seems that a lot of the things are on the positive side, obviously the big gorilla in the room as you’ve mentioned is the economy but I just kind of want to give you one more chance to try to articulate that as your stock is down almost 4% right now?

Well I can’t articulate why our stock is up or down, there are a lot of factors other than just whatever our forecast is going to be, but at the end of the day we’re trying to say we have an awful lot of changes to make in our forecast and we’re just trying to be honest and upfront about it. Some of those changes are going to be positive as we closed the book on the 20%, 15%, 20% that has to be closed. Chances are it’s going to be at lower prices, chances are we’re going to accelerate some transmission. I couldn’t tell you specifically today what our forecast is going to be so, I don’t know how anybody else is going to be. It is what it is. We’re just trying to be upfront and honest that there is going to be a tremendous number of changes in our forecast from the last time we did it. It’s a simple and straightforward statement. Andrew Levi – Avon Capital: Right. Thank you very much.

Thanks Andy.

I would like to turn the call back over to management for closing comments at this time.

Certainly, we like to thank everyone for joining us on the call today and as always we certainly appreciate your support and interest in FirstEnergy. Thanks a lot.

Thank you.

This concludes today’s teleconference. You may disconnect your line at this time. And thank you for your participation.