© 2024 Alpha Spread Limited. All Rights Reserved.
www.alphaspread.com is not operated by a broker, a dealer, or a registered investment adviser. Under no circumstances does any information posted on www.alphaspread.com represent a recommendation to buy or sell a security. The information on this site, and in its related newsletters, is not intended to be, nor does it constitute, investment advice or recommendations. The information on this site is in no way guaranteed for completeness, accuracy or in any other way. In no event shall Alpha Spread Limited be liable to any member, guest or third party for any damages of any kind arising out of the use of any content or other material published or available on www.alphaspread.com, or relating to the use of, or inability to use, www.alphaspread.com or any content, including, without limitation, any investment losses, lost profits, lost opportunity, special, incidental, indirect, consequential or punitive damages. Past performance is a poor indicator of future performance.
You don't have any saved screeners yet
Intrinsic Value is all-important and is the only logical way to evaluate the relative attractiveness of investments and businesses.
Good morning and welcome to CenterPoint Energy's Second Quarter 2018 Earnings Conference Call with senior management. [Operator Instructions]
I will now turn the call over to David Mordy, Director of Investor Relations. Mr. Mordy?
Good morning, everyone. Welcome to our second quarter 2018 earnings conference call. Scott Prochazka, President and CEO; and Bill Rogers, Executive Vice President and CFO, will discuss our second quarter 2018 results and provide highlights on other key areas including our pending merger with Vectren. Also with us this morning are several members of the management, who will be available during the Q&A portion of our call.
In conjunction with our call, we will be using slides which can be found under the Investors section on our website, centerpointenergy.com. For a reconciliation of the non-GAAP measures used in providing earnings guidance in today’s call, please refer to our earnings news release and our slides. They've been posted on our website as has our Form 10-Q.
Please note that we may announce material information using SEC filing, news releases, public conference calls, webcast, and post to the Investors section of our website. In the future, we will continue to use these channels to communicate important information and encourage you to review the information on our website.
Today, management will discuss certain topics that will contain projections and forward-looking information that are based on management’s beliefs, assumptions, and information currently available to management. These forward-looking statements are subject to risks or uncertainties. Actual results could differ materially based upon factors including weather variations, regulatory actions, economic conditions and growth, commodity prices, changes in our service territories, and other risk factors noted in our SEC filings.
We will also discuss our guidance for 2018. The guidance range considers utility operations performance to-date and certain significant variables that may impact earnings such as weather, regulatory and judicial proceedings, throughput, commodity prices, effective tax rates and non-merger financing activities.
In providing this guidance, the company uses a non-GAAP measure of adjusted diluted earnings per share. It does not include other potential impacts such as changes in accounting standards or unusual items. Earnings or losses from the change in the value of the zero premium exchangeable subordinated notes were ZEN securities and the related stocks or the timing effects of mark-to-market accounting in a company's Energy Services business. The guidance range also considers such factors as Enable's most recent public forecast and effective tax rates.
During today's call and in the accompanying slide, we’ll refer to public law number 115-97 initially introduced as the Tax Cuts and Jobs Act, as TCJA or simply tax reform.
Before Scott begins, I would like to mention that this call is being recorded. Information on how to access the replay can be found on our website.
And now, I'd like to turn the call over to Scott.
Thank you, David, and good morning, ladies and gentlemen. Thank you for joining us today and thank you for your interest in CenterPoint Energy.
Since we have some potential new investors on this call, I would like to start with a brief overview of CenterPoint’s vision and strategy. Later in the call, Bill will provide an overview of how we present our financial performance.
Beginning on Slide 5, CenterPoint has a long-standing vision to lead the nation in delivering energy, service and value. We are committed to leadership and have been recognized for our use of technology to improve operations and create a better service relationship with our customers. We have enjoyed these successes due to our simple strategy of operate, serve, and grow.
These three elements keep us focused on safely and reliably maintaining and operating more than $20 billion in assets, making sure our customers receive the benefits of our investments and product offerings and creating growth opportunities for our employees and our investors.
This is done by making the right investments in our energy delivery systems, in the new technologies we introduce to improve efficiency and service quality, in our employees and in the communities we serve. The pending merger with Vectren is well aligned with our vision and strongly supports the elements of our strategy.
Next, I will cover the quarterly results, business unit highlights and full year outlook. Turning to Slide 6. This morning we reported a second quarter 2018 net loss of $75 million or $0.17 per diluted share compared with net income of $135 million or $0.31 per diluted share in the same quarter of last year. This quarter includes a noncash charge of $0.42 per share associated with our ZEN securities primarily as a result of AT&T’s acquisition of Time Warner.
On a guidance basis excluding $34 million of pretax costs associated with the pending merger with Vectren, second quarter 2018 adjusted earnings were $127 million or $0.30 per diluted share compared with adjusted earnings of $125 million or $0.29 per diluted share in the same quarter of last year.
Increases were associated with the lower federal income tax rate related to tax reform, rate relief, equity return primarily due to the annual true-up of transition charges, customer growth and midstream investments.
These benefits were largely offset by higher operations and maintenance expense, depreciation and amortization and interest expense and certain timing impacts due to both the 2017 Texas Gulf rate order and the Arkansas decoupling mechanism.
Utility Operations and Midstream Investments both had a solid quarter. Our performance keeps us on track to achieve the high end of our $1.50 to $1.60 earnings per share guidance range excluding costs associated with the pending merger with Vectren. Our business segments continue to implement their strategies which are focused on safely addressing the growing needs of our customers while enhancing financial performance.
Turning to Slide 7. I will cover business highlights starting with Houston Electric. Electric Transmission & Distribution core operating income in the second quarter of 2018 was $167 million compared to $151 million in the same quarter of last year. We see continued growth in our electric service territory adding more than 34,000 metered customers since the second quarter of 2017.
On the regulatory front, we made a transmission investment recovery or TCOS filing in May requesting an annual revenue increase of $41 million based on a $285 million increase to rate base, which is largely a result of completing the Brazos Valley Connection Transmission project.
We plan to file a certificate of convenience and necessity or CCN with the Public Utility Commission of Texas or PUCT in September for our Freeport Master Plan Project. We anticipate a ruling from the PUCT in the third quarter of 2019. This project is currently included in our five-year plan at a cost of $250 million as filed in our form - in our 2017 Form 10-K.
We now anticipate this project will cost up to $630 million, and we will include this as part of our new five-year capital plan in our 2018 Form 10-K. For a full regulatory update of our current filings, please see Slide 24. Houston Electric is having a strong year and is performing ahead of our expectations for 2018.
Turning to Slide 8, natural gas distribution operating income in the second quarter of 2018 was $7 million compared to $42 million in the same quarter of last year. We continue to see solid customer growth with the addition of more than 29,000 customers since the second quarter of 2017. The variance for the quarter was largely driven by the timing elements I mentioned earlier, and which Bill will discuss in more detail later.
In short, natural gas distribution is performing well and on target to meet our expectations for 2018. Overall CenterPoint is on track with our planned $1.7 billion in capital expenditures for the year. Energy services’ operating income was $7 million in the second quarter of 2018 compared to $10 million in the same quarter last year, excluding a mark-to-market gain of $8 million and $6 million respectively.
We continue to see value from our recent acquisitions and are reiterating Energy Services core operating income target of $70 million to $80 million for 2018. As mentioned earlier, Midstream investments contributed $0.10 per diluted share in the second quarter of 2018 compared to $0.09 per diluted share in the same period last year.
On Slide 9, we’ve captured some of the highlights from an able second quarter earnings call on August 2. Quarterly volumes of gas gathered and processed were at an all-time high since Enable’s formation in May of 2013.
On their second quarter call, Enable stated they anticipated achieving for 2018 the midpoint or higher of their net income attributable to common units, guidance of $375 million to $445 million. We used this guidance as input for CenterPoint’s EPS guidance.
We use this guidance as input for CenterPoint’s EPS guidance.
Turning to Slide 10. We continue to forecast strong earnings growth relative to 2017 and are excited about the second half of the year. Year-to-date for guidance EPS, we are $0.19 ahead of where we were at this time last year.
We anticipate that utility rate relief and customer growth, contributions from energy services, and earnings from Enable will continue to drive growth. We are reiterating our 2018 guidance EPS at the upper end of our $1.50 to $1.60 range, excluding costs associated with the pending merger with Vectren.
Regarding the merger, I am pleased with the integration planning work done to date and look forward to closing the merger with Vectren in the first quarter of 2019. Once merged, we will be better positioned as a leading U.S. energy delivery, infrastructure, and services company.
Over the past couple of months, I have had the opportunity to meet with many Vectren employees. I'm excited by the enthusiasm they share to help build a company that is committed to common values, safety, customers, communities, reliable operations, and growth. I've also met with stakeholders, including regulators, customers, and local officials in both Indiana and Ohio. I believe the stakeholders appreciate our values and the commitment we have to serving our customers.
I'd now like to turn the call over to Bill.
Thank you, Scott.
We recognize that there may be new analysts on this earnings call. Therefore, before I begin the quarter and year-to-date discussions, I want to provide an overview of how we present our financial performance as described on Slide 12. I will start with the GAAP EPS versus guidance EPS when reporting our results. We have adjusted our GAAP EPS for two items to determine guidance EPS.
Those adjustments are mark-to-market impacts at our Energy Services business and the net of the mark-to-market assets and liabilities associated with our ZENS securities and related stocks. We do not adjust for timing-related items, onetime items, or enable related mark-to-market impacts. For a detailed reconciliation, please see Appendix Slides 28, 29, and 30.
We have five business segments within our company. Those segments are Electric Transmission & Distribution, Natural Gas Distribution, Energy Services, Midstream Investments, and Other Operations. The term Utility Operations in our EPS breakout includes the four business segments other than the Midstream Investments segment.
When we speak of core operating income, we exclude the transition and system restoration bonds for Electric Transmission & Distribution and the mark-to-market impacts from our Energy Services. Core operating income does not provide any adjustments to the Natural Gas Distribution segment, nor does it include Other Operations.
With that overview, I will now review the financial performance for the second quarter. On a GAAP basis, we reported a second quarter 2018 loss of $0.17 per diluted share. Earnings included a noncash charge of $0.42 per diluted share associated with our ZENS securities. This $0.42 is primarily due to the acquisition of Time Warner by AT&T, whereby Time Warner stockholders receive cash and AT&T stock.
As with our ZENS accounting for Charter's acquisition and merger with Time Warner Cable in the second quarter of 2016, there were no cash flow or tax impacts as a result of this transaction. Further details are provided on page 22 of the slide deck, as well as Note 11 in our second quarter Form 10-Q.
In order to review our financial performance on a guidance basis, I will begin with quarter-to-quarter operating income walks for our Electric T&D and Natural Gas Distribution segments, then review EPS drivers for utility operations and finish with the consolidated earnings on a guidance basis. My intent is to help investors understand the elements with confidence in achieving the high-end of our 2018 guidance range, excluding costs associated with the pending merger with Vectren.
As we noted in the first quarter, the adoption of the accounting standard for compensation retirement benefits resulted in increased operating income for 2017 as it moved certain amounts below the operating income line.
As you can see on Slide 13, Houston Electric performed well during the second quarter. While revenue and operating income decreased $19 million as a result of tax reform, this decrease is offset by lower income tax expense when looking to the net income line. Rate relief translated into $26 million favorable variance for the quarter and customer growth provided an $8 million positive variance.
Usage accounted for $9 million favorable variance primarily due to a return to more normal weather. Equity return related to the true-up of transition charges increased $14 million. We have provided an updated equity return amortization table and appendix due to our recent nonstandard true-up filing.
O&M accounted for an unfavorable variance of $15 million. Excluding the equity return and the tax reform adjustment, Houston Electric’s operating income increased by $21 million on a quarter-to-quarter basis. Overall, Houston Electric is performing ahead of our expectations for 2018.
Now, turning to Slide 14. Natural Gas Distribution operating income for the second quarter was $7 million versus $42 million for the second quarter of last year. This $35 million decline was primarily attributable to three items.
First, the recording of regulatory liabilities to reflect the decrease in the tax rate from tax reform has a corresponding decrease to revenue of $5 million. As noted in the Houston Electric review, there is a corresponding offset in income tax expense.
Second, the timing of a decoupling normalization accrual recorded in the second quarter 2017 associated with warmer-than-normal weather during the 2016 and 2017 winter season accounted for a $16 million benefit in 2017 that was not repeated in 2018. Third, in second quarter 2017, we had a onetime net benefit of $10 million attributable to adjustments related to the Texas Gulf rate order.
Operating income also included $7 million positive variance from rate relief, a $2 million benefit from customer growth and an $11 million increase in O&M expense. The Natural Gas Distribution segment is performing well and is on track with our expectations for 2018.
Energy Services’ second quarter operating income excluding mark-to-market adjustments was $7 million versus $10 million in the second quarter of 2017. For this business segment, we are reiterating our operating income target for the full-year 2018 of $70 million to $80 million compared to $46 million for 2017, again excluding mark-to-market adjustments in both years.
Our quarter-to-quarter Utility Operations EPS walk on a guidance basis is on Slide 15. We start with $0.20 and subtract $0.02 for core operating income inclusive of Energy Services and excluding equity return. This decrease is a result of items I note in operating income walk for the gas distribution.
Next, we add $0.01 for additional interest expense as a result of higher debt to fund capital investment. We also had additional interest expense connected with our bridge financing. However, that is included in merger-related expenses.
Next, we had $0.02 of improvement from equity return and $0.01 of improvement for other. Other does include the benefit from a lower federal income tax rate. That brings us to $0.20 Utility Operations EPS on a guidance basis excluding $0.06 of merger-related expenses.
Our consolidated EPS comparison is on Slide 16, starting with $0.29 for the second quarter of 2017 and ending with $0.30 for the second quarter of 2018. In short, we are even quarter-to-quarter for the Utility Operations and Midstream investments after a $0.02 mark-to-market charge and a $0.01 net EPS gain.
Slide 17 shows the year-to-date consolidated combined guidance comparison starting with $0.66 for the first half of 2017 and ending $0.85 per share for the first half of 2018. Utility Operations has delivered $0.16 of improvement year-to-date primarily due to the strong performance of our Electric Utility and in Energy Services.
Midstream investments after a $0.03 mark-to-market charge year-to-date has delivered a net $0.03 improvement. With this $0.19 of total improvement year-to-date, we are well on track to meet the high end of our 2018 guidance range.
Now turning to Slide 18. We are providing an update as to key milestones on our pending merger with Vectren. Vectren shareholders will vote on the pending merger on August 28. We made informational filings with the Indiana and Ohio commissions, and a hearing is scheduled for Indiana on October 17. There is no hearing scheduled in Ohio, and no parties intervened or protested our FERC application.
Our plan of financing is unchanged since the first quarter update. We plan to finance the acquisition of Vectren common shares with a combination of $2.5 billion of CenterPoint common equity, mandatory convertibles or other high-equity content securities. The remainder of the acquisition financing will be senior notes and/or commercial paper issued by our holding company and cash.
Additionally, the process for our internal spin of Enable is progressing well and is expected to be completed in 2018 prior to the Vectren merger close. As we have shared previously, we do not plan to sell Enable units to finance the merger.
Moving to Slide 19, the plan of financing is based upon our objective to achieve a consolidated 15% adjusted funds from operations to debt as measured by rating agencies in 2020. We view that with our current business risk profile and this debt coverage, we will achieve BBB or better credit quality for all of our rated debt securities upon closing of the merger.
I will conclude on Slide 20 with our prospective combined company projected rate base. We created this combined rate base slide from year-end rate base estimates provided by us and Vectren’s rate base estimates published in yesterday in their earnings call slides.
CenterPoint’s year-end rate base estimates are consistent with the average rate base estimates that we provided on our February 22 call. Add it together; our investors produce a compound annual growth rate of 7.6% for the 2017 through 2022 period. We anticipate both companies will be updating their capital expenditure plans in their respective independent filings of their 2018 Form 10-Ks.
Finally, we’d like to note our recently declared dividend of $0.2775 per common share. This is an approximate 4% increase relative to a year ago and consistent with our 4% annual increases in dividends over the last several years.
I'll now turn the call back to David.
Thank you, Bill. We will now open the call to questions. In the interest of time, I will ask you to limit yourself to one question and a follow-up. Ginger?
[Operator Instructions] Our first question comes from Ali Agha with SunTrust.
My first question, Bill, I mean - I wanted to just get a sense any further thoughts that - of the $2.5 billion equity in terms of the mix that you're looking at, are we still thinking that the bulk of it will be common, as opposed to mandatory or some other form? And just some sense of how you’re thinking about the timing.
It’s Bill. I think you said it correctly. The bulk of it is $2.5 billion and it's a combination of common equity, mandatory convertibles or other high-equity content securities. With respect to the timing, we have said we intend to complete the permanent financing for the acquisition of Vectren common shares before we close on the merger.
And I guess my second question, Scott, to you, looking at the numbers you've given us on Slide 20 which break out the rate base growth rates for each company separately, on a - if I look at just the CenterPoint component of it, you're growing at about 8.1%, the Vectren numbers are 6.6%, so the combined gets to 7.6% that you pointed out.
I guess the question being that on a stand-alone basis, so rate base growth, which is a good proxy for earnings growth, in my mind, is actually higher. So, again, I'm not quite clear what Vectren would bring to the table given that it's actually diluting your rate base growth rate.
Ali, the way I would respond to that is they have - still have a very strong growth rate on their rate base given their capital plans. Their plans, as they have shared them, or their expectations involve growth in both their regulated businesses and their unregulated businesses.
And when you look at the growth opportunities for that complete set, matched up with our set, we think they're nicely complementary to our growth rate. So this is just taking a look at the utility side.
I will also say that each year, both companies or all companies update their capital plans based on requirements going forward. But there - as you pointed out, their growth rate is technically lower than ours on the utility side, but they anticipate other growth in some of their non-regulated business units.
Your next question is from Julien Dumoulin-Smith from Bank of America.
So I wanted to follow up on the sale - well, basically the financing composition here. Can you perhaps elaborate a little bit on your latest thoughts on Enable just in the context of ongoing equity needs, independent of the sale, and also with respect to the sale, the composition of equity and equity units, if you have any further thought process in and how exactly you want to structure it?
So, Julien, I don't think we have any more to share on the composition piece in terms of our equity other than what Bill just shared a minute ago. And with respect to Enable, look, right now, we are focused on the financing of this transaction.
What we have said is following the transaction, we will have some modest equity requirements to fund the capital requirements of our businesses going forward. And at that time, Enable may be a source of funds for that. But at this point, we're focused on completing this transaction and the necessary financing for it.
And can you elaborate a little bit – I mean, you just discussed a little bit already around the creative nature to rate base of the Vectren acquisition. Can you comment a little bit more specifically around the electric versus gas versus non-reg contributions to that future rate base? Or let's keep it with electric versus gas, just to keep the focus on rate base specifically. But altogether, I mean, I know that this is perhaps separate in the $50 million to $100 million pre-tax that you've talked about, but just getting a little bit more of a sense as you had more time to look at the business.
Yes Julien, I don't think we're prepared at this point to comment on the rate base growth deltas by business unit at this point. We are, for context purposes, about three weeks into our integration planning exercise. So we are at the front end of understanding more information about the specifics that would - we will pursue once the deal is closed.
Or maybe let me specify a little bit more carefully. Electric, on the Vectren side historically, has seen a little bit more rate inflation and so, therefore, I suppose has had a little bit more of a difficult time accelerating their growth.
Could you see merger-related benefits accruing such that Electric could see a disproportionate growth again? Or are we talking principally about the sizable growth at gas and just continue to accelerate on that front?
Well, again, it's probably premature to be talking about their capital plans. But they do have appreciable spend in both their electric and their gas businesses, if that's helpful.
Your next question is from Michael Weinstein from Credit Suisse.
Could you talk a little bit about the Freeport plan and the reasons for the substantially increased costs? I mean, just looking at the 10-Q and I see that some of it’s related to environmental, and I'm wondering if maybe Hurricane Harvey had something to do with that or – and then, also, as a part of this question, maybe address the – how you think regulators might react to this, to the extent that you've already talked to them about these increased costs.
So, Michael, to your first question, the driver for the increase from the original estimate of 250, that estimate was made early on when we were considering, at a high level, different routing options.
During the time between that estimate and the one we just provided, we were able to do much more refined analysis about routing options and the structures needed to be able to withstand certain wind tolerances, as well as recognition of environmental wetland-type areas that are in this region of our service territory.
When you couple the design requirements, including all of those factors, we end up with a cost for this line that has gone up from the 250 up to the number that I specified at around 630. So that's really the driver. It’s structure and environmental-related routing issues. It’ll be the short answer to that. Go ahead.
And a regulatory commentary on this so far, I mean I'm presuming you've already put some thoughts here?
So this is something that is just now entering the process with the Commission. We will be presenting that to them as we make our filing. But one point to note, this is an investment that was deemed necessary by ERCOT as a result of reliability needs in the region. So, we still see this as a solution to solve a reliability-related design issue and I still believe it’s the most cost-effective solution available.
Our next question is from Michael Lapides from Goldman Sachs.
Thanks for taking my question. Just thinking about taxes and on the electric side, can you talk to us a little bit about demand trends that you’re seeing specifically – weather normalized, obviously – but specifically across the customer classes, what’s coming in a little bit higher than maybe what you would bake in? What’s coming in a little bit lower than maybe what you anticipated and maybe what the drivers are?
What we're noticing around the Texas area is really strong ongoing demand in the commercial and the industrial sectors. That's what tends to be driving overall throughput along the system as well as some weather-related. But you asked for kind of weather-normalized. Those two segments tend to be weather-normalized automatically.
We still continue to see strong demand with our residential sector. They are essentially on a use per customer basis holding flat, which is what we've seen for several years now. We will note that we have seen a slight downturn in the growth rate associated with residential addition.
We believe that's associated with Hurricane Harvey and the impacts that had on residential meters. And I think we're going to see noise in that growth rate until we pass the period in which Harvey occurred which would be in the fall. So, that's creating some noise.
We also had a surge in the most recent period of completing multiple multi-family units. And multi-family unit construction has slowed now while the inventory is being consumed. But our additions in, say, a more of a suburban setting continue to be strong. One of our indications for that is we have joint trench crews. These are crews that go out and put in the infrastructure ahead of development build. These crews are operating at a level that is higher than last year, for example. So we see good fundamentals that even though the residential count is lower that the residential demand is still very strong.
Can you talk to us a little bit about what is your kind of all-in demand growth that you embed in your multi-year guidance?
We think about 2% overall.
Your next question is from Greg Gordon from Evercore.
Two questions. One, it doesn't seem that – like that big of an issue, but there was a $3 million delta quarter-over-quarter in the Energy Services businesses. Now, you’re obviously still pointing to confidence in your guidance range for the year, so I'm sure it's quarter volatility. But can you just go into little more detail as to what would cause that?
There was a little bit of volatility in the quarter. But as you pointed out, it's a low quarter anyway, so any amount of volatility gets exacerbated. We did – we made some adjustments. There were some adjustments that we made on the balance sheet that had an effect and fairly minor in nature. But again, since the number is small on this quarter, it got amplified.
Okay.
The fundamentals – I’ll just say the fundamentals remain very strong in this business. Customer count is up. Our throughput is up. Margin is staying very healthy. So, we're still very bullish on this space.
That's the answer. There was no shift in underlying fundamental trends in the business.
No, there was not.
Second question is, unless I'm mistaken, I don't think you've announced the full suite of who's going to be your senior management for the pro forma company other than you definitively being CEO. Is that correct? And if that is, when will we get a fuller sense of who the management team is going to be?
That is correct. I have not announced it. And as for timing, waiting until later in the process. I'd like the decision-making to be informed by our integration planning process. So it will be a little later on the process before I get to that point.
Your next question is from Zach Prince from Merrill Lynch.
Hey, guys. It’s Antoine actually. How are you? Quickly on the – and apologies if I missed it, but the way you guys are in the restructuring of CERC.
I will let – I’ll let Bill answer this.
Antoine, good morning. As we said, we should be completing that at year-end this year where our investments in Enable Midstream that are held at the CERC level get moved to a separate entity. We call it CenterPoint Midstream. And then we put leverage against those investments, and the use of the proceeds from those borrowings will be to pay down debt at CERC and to pay down debt at the holding company.
And for CERC, there will be – supposedly to reach the debt-to-capital ratio?
Yes, the target debt-to-capital ratio for CERC is the weighted average debt-to-capital ratio that we have for the Utilities and CERC.
And would Energy Services be included in that?
For this time, Energy Services will remain part of CERC.
[Operator Instructions] Our next question is from Steve Fleishman from Wolfe Research.
Old investor, not new investor. So just on Enable, so if you go back to the last 12 months or so, obviously, it's been a tough environment and you've mentioned a few times in terms of thinking about monetizing. There had been some times of that changing. So maybe just from that standpoint, is that ignoring
So maybe just from that standpoint, is that ignoring that you don't need it for the merger, or just is there A better environment now for you to think about monetization of some of the stake?
Well, clearly, Steve, with the strengthening in the market, that space, that is a positive sign. We'd like to see that. We continue to monitor that market for strength of investors. But I would answer the question by saying, look, our near-term focus is around financing the acquisition and keeping our attention on that. And then to the extent that there would be opportunities for Enable, it would be down the line when we're looking at equity requirements for our ongoing growth capital.
And then one other question on just the 2018 guidance, I wanted to clarify you're still using the midpoint of the Enable range. And also, did you – are you including any of the good July weather, which I guess we pay attention to on the power side?
Steve, it's Bill. Our guidance at the high end of our $1.50 to $1.60 incorporates Enable’s guidance when they say they're at their midpoint or higher. With respect to July weather, yes, it's been somewhat warmer-than-normal weather. But to date, we haven't updated for third quarter activities. This is just through second quarter.
Okay. There are no further questions in the queue. I would like to turn it over to the leaders for any closing remarks.
Thank you, everyone, for your interest in CenterPoint Energy. We will now conclude our second quarter 2018 earnings call. Have a great day.
This concludes CenterPoint Energy's second quarter 2018 earnings conference call. Thank you for your participation.