Srikanth Maddipati - CMS Energy Corp. Patricia K.

Poppe - CMS Energy Corp. Rejji P.

Hayes - CMS Energy Corp.

Michael Weinstein - Credit Suisse Securities (USA) LLC Jonathan Philip Arnold - Deutsche Bank Securities, Inc. Ali Agha - SunTrust Robinson Humphrey, Inc.

Paul T. Ridzon - KeyBanc Capital Markets, Inc.

Travis Miller - Morningstar, Inc. (Research) Gregg Orrill - Barclays Capital, Inc.

Jonathan Donnel - Scotia Howard Weil

Thank you. Good morning and thank you for joining us today.

With me are Patti Poppe, President and Chief Executive Officer, Rejji Hayes, Executive Vice President and Chief Financial Officer, and Tom Webb, Vice Chairman. This presentation contains forward looking statements, which are subject to risks and uncertainties.

Please refer to our SEC Filings for more information regarding the risk and other factors that could cause our actual results to differ materially. This presentation also includes non-GAAP measures.

Reconciliations of these measures to the most directly comparable GAAP measure are included in the appendix and posted on our website. Now, I'll turn the call over to Patti.

Thank you, Sri. Good morning everyone.

Thanks for joining the call. It's great to be with you this morning.

I'll be sharing our first half results and then operational update. And then Rejji will give the details of our first half financial performance and our outlook.

Our stance for people, planet and profit will be reflected in our presentation today. And frankly, it's what we work on every day.

Our ability to commit to all three is enabled by our performance which we're continuously improving to the CE Way. I look forward to sharing our latest updates and not to worry, I've got a great story of the month for you.

We are happy to report, in spite of record breaking storms in our service territory and mild weather in the first half of the year, we're up 7% on a weather-normalized basis. And perhaps more importantly, we're ahead of our plan by $0.04 year-to-date.

And therefore, we are reaffirming our year-end adjusted EPS guidance of 6% to 8% or $2.14 to $2.18. As you've come to expect, our delivery of profits takes the form of a consistent 7% growth over the past 14 years, no matter the conditions we face.

Because we're confident about that continued consistent performance, we continue to reaffirm a range of 6% to 8% EPS growth for this year and many years to come. In tough external conditions, consistent top-end financial performance only comes through extraordinary efforts of extraordinary people, one of the cornerstones of our triple bottom line.

Now, we've been best-in-class in employee engagement for several years but we must confess we were thrilled to be named the number one employer in Michigan in the annual Forbes best large employer survey in May. And it's no coincidence that the customers served by this engaged team have named us a Most Trusted Brand through a survey conducted by Market Strategies International.

As a result of the Energy Law passing in December, our regulatory calendar is full and active. We recognize and appreciate our MPSC staff and commissioners for all their hard work.

The Energy Law implementation is going well and it's on track. The MPSC Chairman, Sally Talberg, has done a great job of organizing the working groups and leading a very systematic process to implement this high value legislation.

The state reliability mechanism is being evaluated and designed as we speak. It's scheduled for a final determination in December with a June 2018 implementation.

Our energy efficiency team is ramping up the new 1.5% electric and 1% gas energy efficiency targets, enabling the new incentive mechanism to go into place. And simultaneously, we have a gas rate case that's scheduled for a final order this coming Monday and our electric rate case will be self implemented in October.

Finally, our Palisades early terminations securitization is scheduled for a final order at the end of September. Though this proceeding has no impact on our earnings and it is not baked into our plans, we do believe that this early termination is in the best interest of Michigan.

We don't have too many opportunities to save our customer's $45 million a year, so we would love to pass this along to them. We also believe that the early termination of this out-of-market PPA enables the Governor's energy agenda through the elimination of energy waste and improving energy affordability in Michigan, while not jeopardizing the liability as a result of our replacement plan, which serves both people and the planet.

Our promise to improve the planet is coming to fruition at a rapid rate. The closure of our seven coal plants in 2016 moved us from 49% coal generation to 22%, more coal retired than any other investor-owned utility in the nation.

Our actions resulted in a reduction in carbon intensity of 30% and ranking us as the number one U.S. utility by Sustainalytics, and we aren't finished.

Our clean and lean strategy enables further coal reductions without big bets to achieve the replacement. Fulfilling the RPS standard and providing for large business customer preferences for renewables creates the perfect conditions to modernize our generation fleet in a cost efficient, low-risk way.

Now when we talk about our commitment to the planet, we're talking about reducing our environmental impact including reductions in water, land use, emissions and carbon. We've self-imposed improvement targets that go beyond environmental compliance and we're ahead of our plan in all of these areas.

There was a time when this would have implied higher costs for customers, but not at CMS. We find a way to deliver the and in clean and lean.

Lean has many descriptors and attributes. One of which is the concept of waste and waste elimination.

An example of waste in our business is the under utilization of assets. Traditionally, generation planners forecast low growth, build a plant big enough to serve that growth and add additional spending reserve.

We see modular additions of renewables as a more flexible way to provide adequate supply resources with smaller bets and less potential waste. Modular renewables are a great choice for us because we have ample capital opportunities outside of generation.

We have more upgrades than our customers can afford across the entire business. So we're always making choices that maximize customer benefits, while at the same time reducing costs so we can deliver more customer value for every dollar invested.

Our customers will benefit from investments in our backlog of upgrades on our grid and on our gas system, and our investors can rely on a sustainable growth strategy. In addition to our own vision for clean and lean generation fleet, the new Michigan Energy Law requires and our customers are asking for more renewable energy.

We're expanding our Cross Winds II wind park to grow toward our 15% RPS standard. We conducted an RFP and we were the most competitively priced bidder, therefore, we're building that expansion ourselves.

In addition, to our renewable expansions, we worked closely with some of our largest and most energy conscious customers to develop a pricing package that both meets their desired price points and their commitment to the planet. We recently requested approval of this pricing option with the MPSC.

This pricing design can enable real attraction to our service territory and serve as an important part of our economic development strategy to grow Michigan. Our residential customers don't want to be left out of the mix.

To serve them, we've launched our Solar Gardens, a utility scale community solar program and a pilot to operate rooftop solar package for residential and small commercial customers. These are clean alternatives delivered with a lean mindset.

Our lean mindset carries over to all of our investments. For example, the deployment of our smart meter technology has improved our meter reading accuracy and rate, but we did not just rely on technology deployment.

We simultaneously improved the work process through applying our CE Way skills. In fact, the remaining meters to be read for our gas-only customers and customers that have opted out of smart meters can be very inefficient to read, but for our meter reading team's improvement efforts.

And the results are frankly stunning. We've improved the read rate to 99% and improved reads per hour by 45% year-over-year which contributed to ancillary benefits such as 64% reduction in invoice reworked and a reduction of 2 million calls to our call center.

The net impact, over $8 million of savings since 2015, while at the same time, improving the customer experience, do more accurate billing and virtually eliminating estimated meter reads. We use these cost savings to offset the capital investment in infrastructure, which delivers the value our customers deserve and helps keep rates affordable.

This is a great example of our business model put into action and it's not even my story of the month. My story of the month is about a fueling pilot in our Flint service center.

We have a vision of blue and white pulling out of our 43 service centers all across Michigan every morning after a quick safety briefing and a daily huddle, ready to serve. One thing that slows down our crews today is the time they spend gathering materials, equipment, fueling their vehicles, but this is changing.

We've started a pilot in Flint where lower cost night shift has been established to pre-fuel the vehicles and have them prepped and ready to go before the crews arrive in the morning. In Flint alone, this is saving 15 to 30 minutes per person daily.

When we extrapolate this to a statewide implementation, the savings potential grows to an elimination of over 100,000 hours of wasted time per year. We can replace those wasted hours with time for our crews to do the value adding work that our customers need.

I'm reminded every time we are implementing one of these seemingly simple improvements that we're just scratching the surface of our full potential. You can definitely put this story in the low hanging fruit category.

It's what gives us the confidence that we have lots more cost savings opportunities that deliver a better customer experience. Our commitment to the triple bottom line powered by performance and the CE Way is why we are so sure that we can continue to improve the experience for our customers and sustain the performance you've come to expect.

This model's been working for more than a decade. And in spite of many changes that are outside of our control, come what may, the CMS team will deliver for our customers and our investors.

Now, I'll turn the call over to Rejji.

Thank you, Patti, and good morning everyone. As we have highlighted in the past, we deeply appreciate your interest in our company.

We view the investment community as a key element of the people aspect of the triple bottom line, alongside customer's employees and everyone we serve. Our second quarter results of $0.33 per share, down $0.12 from last year, largely due to continued mild weather and record storm activity in our service territory.

Put the level of storms into context, year-to-date, we've had five official major event days in 2017, compared to three for all of 2016 which led to approximately $31 million in service restoration costs through the second quarter which is more than $10 million above our five year average at this time of the year, and roughly double the amount spent in the first half of 2016. With that in mind, we don't make excuses, and already have taken steps to mitigate the unfavorable weather impacts.

For the first half of the year, adjusted earnings of $1.04 per share were flat from last year and up $0.08 or 7% on a weather-normalized basis, which positions us well to meet our annual financial objectives. As Patti mentioned, we're quite pleased with our performance to-date and remain $0.04 ahead of plan, even with the unfavorable weather and record storm activity in the first half of the year.

As indicated in the waterfall chart, we have managed to offset $0.11 of mild weather and record storms fully in the first half of the year with cost savings, out performance at enterprises and rate relief net of investments among other factors. Our business model which focuses on achieving cost savings coupled with modest sales and other countermeasures to minimize customer rate inflation has enabled us to end the first half of 2017 ahead of plan which bodes well for the remainder of the year.

For the second half of 2017 we have assumed $0.07 of additional rate relief net of investments, and as always we're implementing numerous cost control measures. Lastly, we will also benefit from the absence of discretionary activities which occurred in the second half of 2016, such as our debt pre-funding and relatively high volume of donations, some of which equates to $0.14 of potential EPS pickup in the back half this year.

In summary, we believe these factors provide us with significant flexibility for the rest of the year. As such, we remain highly confident in our ability to deliver 6% to 8% adjusted EPS growth in 2017.

I know you all are well acquainted with this EPS forecast curve which illustrates our progress on meeting our targets or meeting our earnings targets as we move through the year. This year, we started out with mild weather and significant storm activity, but took actions to remain ahead of plan in the first half of the year.

This chart also overlays the curve from 2016. As highlighted, we enjoyed favorable weather and great cost performance in the second half of 2016 which permitted substantial reinvestment back into business in the fourth quarter.

This, as you can imagine, makes the comparison a bit easier for 2017. So we're right on course for another solid, predictable year in 2017.

EPS curves for the past decade remind us that every year is different, but the results were the same. We delivered consistent industry leading EPS growth by managing the business on behalf of customers and investors.

During periods of better than expected weather and cost performance, we have reinvested in the business as evidenced by the $340 million in aggregate that we've put to work over the past four years to achieve customer improvements. Conversely, during periods of unfavorable weather or other unexpected negative variances, we've made up the difference through cost savings and good business decisions without compromising our commitments to our customers and employees.

Irrespective of the circumstances, we have managed to deliver within our earnings guidance annually and this year will be no different. Having spent a good deal of the past three months with the investment community, many have asked how CMS has achieved and will continue to achieve consistent industry leading earnings growth without raising customer rates above inflation year-in and year- out.

Admittedly even I asked this question when I was on the outside looking in. Well the answer is that we have a robust capital plan of needed customer investments largely funded by annual cost savings of 2% to 3% a year, modest utility sales growth and other enhancements such as thoughtful tax planning which eliminates the need for dilutive block equity issuance worth about 2%.

All of this equates to a self-funding roughly 70% of our capital plan which minimizes customer rate impacts to level at or below inflation, while our growth continues at 6% to 8%. This simple, but unique business model has driven our historical success and offers a sustainable path forward to benefit our customers, investors.

Our customer driven capital plan is comprised of needed investments, which will enable the delivery of safe, reliable and efficient electricity and natural gas to those we serve. We've forecast a base case of approximately $18 billion capital investments over the next 10 years in alignment with our clean and lean strategy, which Patti highlighted earlier.

As we've noted in the past, we anticipate additional opportunities of approximately $7 billion in the form of enhanced gas infrastructure, grid monetization and cost efficient PPA replacement through renewables and other sources. As always affordability from a customer and balance sheet perspective, commission alignment and execution capabilities will dictate the pace at which we take on such opportunities.

As to the latter point around execution risk, this slide illustrates our confidence in our ability to execute on our 10-year plan. As highlighted, over 90% of our 10-year capital plan of $18 million is represented by projects less than $200 million in size which compares favorably to our capital plan composition over the past 10 years.

Broadly speaking, project size offers directional guidance as to the complexity and duration of projects. As such, our capital plan is not only increasing in size but is decreasing in terms of risk profile which bodes well for customers and investors.

Our capital plan embodies the modular nature of the clean and lean strategy and perpetuates our no big bets investment velocity. A key driver of our ability to execute on our capital plan in an affordable manner is made possible by lean thinking and performance which drives sustainable cost savings.

As you can see on the left-hand side of the slide, CMS has been a leader in this area and our employees have embraced CE Way to continue to come up with new and innovative ways to deliver those savings to our customers. For investors, this creates capital investment headroom and fulfills our self-imposed commitment to keep base rate increases at or below inflation.

Over the last decade, we have been able to reduce our O&M costs by more than 3% per year and the past three years have been no exception. We're projecting conservatively to continue at this pace at about 2% over the next three years, without compromising our commitments to customers in the form of service upgrades, and while keeping employee salaries and benefits competitive, two key constituents and the people element of the triple bottom line.

Our capital investment strategy in support of regulatory outcomes coupled with annual cost savings and tax planning have enabled us to grow operating cash flow by about $100 million annually. In fact, we've increased our operating cash flow by $1.8 billion in aggregate since 2004.

Our past and prospective cash flow generation has and will continue to eliminate the need for dilutive block equity issuance going forward which further supports the self-funding strategy. For reference, as of June 30, 2017 we've generated over $1.1 billion of operating cash flow which is slightly ahead of plan and the corresponding period in 2016.

Switching gears to sales, the economic outlook for service territory, particularly in Grand Rapids, the largest city in our service territory and in the heart of our footprint remains relatively strong as indicated on this slide. As stated in the past, we don't rely heavily on sales growth as evidenced by our forecast of 0.5% to 1% for 2017 while we continue to be encouraged by the increased expansion and diversification of our service territory.

We continue to work closely with the governor's office, the legislative branch and the key regulators to bring business to Michigan because we win when Michigan wins. Moving onto enterprises, DIG continues to drive the performance of this business unit.

Enterprises was ahead of both the plan and the corresponding period in 2016 due to operational efficiencies attributable to upgrades completed in 2015 and higher capacity prices. As you'll note on the bottom of the slide, capacity remains open in the future years to take further advantage of attractive pricing.

As Patti noted, we'll have more visibility on the Palisades result by the end of September which will dictate our longer term plans for DIG. And as stated in the past, we remain cautiously optimistic as to the outcome of the Palisades' proceeding but have not factored that pending decision into our plans.

As we approach the back half of 2017, we continue to evaluate potential risks and corresponding mitigating factors to minimize volatility in our plan as evidenced by our sensitivities slide. A noteworthy opportunity includes energy efficiency incentives, which were doubled under a new Energy Law but we have only accounted for half of the increase in our financial planning with another $0.02 of potential upside yet to be reflected.

In closing, the last slide provides a reminder of our financial objectives for 2017, all of which are well on track. Needless to say, we remain acutely focused on delivering another year of consistent industry-leading growth with minimal rate impacts to the benefit of customers, investors.

At this point, Brandon, please open up the line for questions.

Hi, good morning.

Good morning.

Good morning, Michael.

Hi. I was wondering if we could talk a little bit about the RFP or the process that's ongoing at the Commission for securitization to improve securitization of the payment to Entergy as well like, what timing do you see on that.

And then also, what kind of timing do you see on getting a replacement for Palisades that you did dig (22:27) into?

Right. So just a couple of high level dates.

So first of all, we expect the order from the Commission on the securitization at the end of September. And keep in mind that's just approving the financing mechanism for the payment to Entergy of $172 million.

And then after that we'll be – and they may provide some color in that order about the replacement plan but the replacement plan really is filled out in a forward-looking rate case that we'll be filing later. So it is definitely a process.

Now they may give some clear indications that say they want us to sign a contract or they give indications they would want us to bring DIG for example into the utility, but none of that would be necessary. We don't expect that to be binding.

We expect the really just the order to be about the securitization and then forward cases about the backfill plan.

Right. Hey, Rejji, you made an interesting comment, you said that as an outsider looking in you were skeptical of how CMS could achieve growth you know without that large cost increases on rates.

And I'm just wondering if what have you learned since you've gotten there that has surprised you.

Yeah. Well, first I would say skeptical as a paraphrase that was not a quote, but I would say I've been pleasantly surprised on the inside now at how well the company has managed to not only execute on its capital plan, which as you know is quite robust as well as risk mitigated, but also to realize significant savings year in and year out.

And so you're familiar with that slide where we show our benchmarking relative to sector and that's a real achievement of O&M cost reductions of 3% per year over the last 10 years. And if you look at the next three years going forward we think that there are significant opportunities to realize additional O&M cost reductions.

We've talked about this in the past, but you know candidly, I would submit that a lot of the cost savings we've realized in the past are really through sheer will and just a lot of good discipline. But through the CE Way we think we can offer much greater level sophistication in realizing cost savings in a scalable and replicable way.

And so we think a combination of process-oriented related savings as well as technology-enabled savings through smart meters and other measures should continue to lead us down this path of consistent cost reduction in the years to come. So I've seen a lot of opportunities within these walls.

And if you look at some of the other metrics that Patti highlights in our stories of the month, there's a lot of low hanging fruit here. And so that's what encouraged to me that this path we've been on for so long is sustainable in the long run.

One last question on the – you said that there was a filing at the Commission to approve your packaged renewable offering, right, to customers that's going to be competitive. Can you just talk a little bit more about that?

What kind of an approval you're looking for and when that might come?

Yeah, so it's a tariff and they do have to approve that tariff and there's a range of time. In the next couple of months, we expect to hear the results of that tariff approval.

So, what we like about it and what we think is particularly unique is that it does not have a cross cost shift. It really provides the access for our large business customers to have access to renewable energy.

They remain a full bundled customer, but then they're able – they have a couple of options they can either bring their own PPA, which we're agnostic to or we will provide the renewables for them and they can then sell that on in MISO. And if prices go up then they get the upside because we've signed a fixed contract with them so that's very appealing to them.

What's appealing to us is they remain full bundled customers and we're able to provide the energy in the form that they prefer. So what we've heard from our large business customers is I mean a direct quote from one of them was this is the first time a utility has figured this out.

This is exactly what we need and it makes Michigan very attractive. So we're optimistic that the Commission will approve the tariff especially since it doesn't have any kind of cost shift to others.

Is that something you expect to happen in the next month or two or is this kind of a rough...

Yeah. In next 90 days we expect an outcome.

Got it. Great, thank you.

Yeah. Good morning guys.

Good morning, Jonathan.

Good morning, Jonathan.

Quick – so I was just looking at your 2017 first half to full year bridge slide, I think slide 13 and you're showing first half cost savings of $0.04 through the first half but it was $0.08 through the first quarter? And just kind of judging by how you tend to manage the business, I would have thought that you would have been pushing for more cost savings outside of storm, given the storm experience you were having during the quarter.

So just curious why we've seen the cost saving number reverse in the second quarter.

Well, I wouldn't say it's necessarily a reverse, Jonathan. This is just the math.

If you're specifically referencing on slide 13 or slide 14 this bucket we have here of what bridges the gap, if you take into account the rates and investment or the rate net of investments and then the $0.12 to $0.16 with six months to go. Well, the reason why we feel confident in our ability to close this gap is that we have all of these activities that we've put in place which are really discretionary in the second half of 2016, which we don't need to replicate in this year, as we think about closing this gap.

And so the only specificity we have is, as it pertains to the cost savings as other is just this math here that closes the gap between the discretionary items that we won't have to replicate again in 2017 and then there's cost savings in other line item, that gets you the $0.12 to $0.16. But we believe that we can realize cost savings beyond that.

So just to be clear that number is effectively just a plug here for illustrative purposes, but we believe we can realize more cost savings over the course of the second half of the year. We're already seeing that in the form of customer operations billing.

Patti highlighted a lot of good achievement (28:54). And we think there are much more cost things beyond what's just on this page.

So again the math here is more for illustrative purposes that just closes the gap on the $0.12 to $0.16, but we think there's a lot more opportunities on that going forward.

But the fact you are $0.08 a head of savings plan or you were getting $0.08 benefit from cost in the quarter it is only $0.04 in the first half, can we just kind of dig into that a little?

So in the first half we had improvement in benefits of about $0.04 and that was largely due to an accelerated pensions funding that we did in the fourth quarter of last year. So that helped us out by $0.04.

And then we had some other good news on property tax related to our Zeeland plant in the first quarter of the year. So that drove a lot of the performance.

But as we go into the second half, again, we have additional cost savings that we have factored in the plan, again, that should help us get through to the second quarter through to the second half of the year, and get us to our guidance of $2.14 to $2.18.

Okay.

So again – sorry.

No, sorry. Okay.

I guess, I would just add Jonathan too, remember we don't work to the quarter we work to a year end number. And we're – as you know our little S-curve that's on slide 16 shows that every year is a little different and the comparison sometimes from one quarter and one year to the quarter before.

It's not necessarily reflective of the year in confidence which is what we're trying to express with our re-affirmation of our year-end guidance. We feel real good about the full year performance.

That's what we're working to.

Okay. And then, Rejji, you did allude to the fact you feel that this cost savings number for the second half is kind of a (30:37) things that you just have coming to you anyway.

So you did have continued storm and/or unfavorable weather. Can you give us some sense of how much you think you could flex the business if you get further headwind?

Yeah. So we're already anticipating if you look again on slide 13, if we have a weather-normalized second half of the year that will cost us $0.07 because we obviously had a very nice second half of the year in 2016.

And we think rates net of investments, again, that's comprised of our electric self-implementation and then where we end up on gas, the gas rate case in this upcoming Monday and so that should offset the weather. And then as you look at the latter portion of this year, we think that a combination of cost savings and again discretionary activities that we executed in the second half of last year, because we had a very good summer and had the opportunity to reinvest back in the business.

We don't have to replicate such activities going forward. So we think a combination of those, or the lack of those activities, or the absence of those activities coupled with uncollectible account (31:43) and we also have some items that we've forecasted rather conservatively at the parent level that we could potentially defer going into 2018.

The combination of all those items should get us through to next year.

Okay.

Through our guidance for this year.

Great. Could I just ask one other thing?

I noticed on the cash flow side, the NOLs and credit line now has $700 million in 2020 and 2021 where it was only 200 last quarter. Seems that has been a change at the back end there.

Is there anything to explain that?

Yep. So there are couple of changes that have come about reflected in our NOL and credit, so you're referring to that bottom yellow row on slide 20.

Yeah, yes.

Sorry.

Yes. It dropped off pretty much, much faster before.

Yeah. So what we're seeing there is obviously, we have to plan to invest about $1 billion or so to get to our RPS standard of 15% as stipulated by the Energy Law.

And so, obviously, by increasing our estimates for capital expenditures related to renewables that does help the balance of NOLs and credit we have forecasted for the next four or five years. And, again, as we sit here today, we don't expect to be a federal tax payer all the way through 2020.

And so we only start paying a portion of federal taxes come 2021. So a lot of it has to do with basically pulling forward spending to meet the new RPS standard.

Does effectively could help to defray equity a little further?

Precisely. And so, again, we do not anticipate through our five-year plan issuing dilutive block equity in the next five years or even beyond that potentially.

Great. Thanks for all the help.

Thank you.

Thanks, Jonathan.

Thank you. Good morning.

Good morning.

Good morning, Ali.

Morning. First question, you know I noticed that in the second quarter the weather-normalized electric sales actually decline.

They were down 0.4%. Does that still keep you on track for the plus 0.5% to 1% you're budgeting for the year, anything particularly that caused that decline?

Yeah. It's a good question, Ali.

We have said for some time now that we foresee weather-adjusted electric sales of 0.5% to 1%. And as you may recall in Q4, on the Q4 earnings call and also in the Q1 earnings call, we historically had attributed that to strong performance in the industrial side.

And we have very good visibility on the performance of that segment as you probably saw that has been tailing off quite a bit. But what encourages us and the reason why we still feel good about that 0.5% to 1% percent forecast is we are seeing a wonderful trend in terms of sales mix.

And so our residential performance has been well in excess of our expectations, and so we're about 0.5% up for residential on the electric side on a weather-adjusted basis, and almost 2% up for commercial. And so we're seeing a nice bit of favorable sales mix, which gives us confidence in that 0.5% to 1%.

And what I would also say just peeling the onion a bit on industrial, the downward trend you see for industrial, that's largely attributable to our retail open access customers and then one large customer who has had lower than expected performance. And so there is a lower margin customers and our remaining balance of industrial customers have performed quite well.

And so we feel very good about the 0.5% to 1% weather-adjusted sales forecast.

Okay. And then secondly, more conceptually, when you talk about the ability to keep customer rates at or below inflation, one of the categories that you put in that is the no-block equity requirement.

So I mean intuitively, you know, the equity whether you want to issue or not shouldn't have a direct impact on customer base, but to interpret that, is that saying to get to the 6% to 8% growth rate to solve for that equation, the fact that you don't need equity helps you in keeping customers rates down, is that the way to interpret that?

That's exactly right because, obviously, if you issue a significant portion of equity, it's going to be dilutive on your earnings. And so we take pride in the fact that we have enough capability on the cost cutting side to fund a good portion of that capital investment backlog execution, the $18 billion plan.

We've been realizing cost cuts to say 2% to 3% over the last 10 years and are forecasting that going forward. And so that coupled with the very good tax planning that has allowed us to not pay federal taxes for the last several years and for the next four or five years forward.

Coupled with a little bit of sales performance at the utility has enabled us to avoid doing those real dilutive block equity deals which others may need to do and that obviously keeps our EPS right where we'd like it to be at that healthy 6% to 8% adjusted growth level.

Right. And then as you mentioned the gas rate case decision should be coming out next week.

Currently there is a slight variance between your last authorized electric ROE and gas. For planning purposes, do you assume that they would align and that 20 basis point reduction that you're seeing in electric that gas probably gets to the same level?

So, just to align on the facts, so we requested to be clear a 10.6% ROE for the gas rate case, obviously, as a result of the self-implementation order as well as what we're seeing in terms of some of the other data points (37:25) expectations have been tempered. And so we have assumed a double-digit ROE to be sure.

And you know there may be a chance that we get to at levels either obtained by DTE in recent cases or closer to electric. And so we'll see where we end up, but it's I think a little early to speculate as to where we may end up on the gas rate case.

Yes. Thank you.

Thank you.

Good morning, Patti. Good morning, Rejji.

Good morning, Paul.

Good morning, Paul.

Just a clarification. Are you $0.04 ahead of plan on a weather adjusted basis or absolute?

Absolute.

Okay, great. And then, Rejji, you mentioned that you've got $0.02 in your hip pocket around energy efficiency.

How challenging is that to execute?

Yeah, I'd say if you look at our track record over the last couple of years, we have been quite good at realizing the required reductions on electric and gas and so. In the prior energy law, you needed to get basically a 1 gigawatt hour reduction on the electric side and 0.75 billion cubic feet reduction in gas and that is now changes for the new Energy Law to 1.5% and 1% for electric and gas respectively.

And then you get now 20% of the cost to achieve those savings. And so we feel good about our ability to execute on that.

What remains to be seen is how much of that upside we can realize in this year because as you may know, the new Energy Law came into effect in April of this year and so there's only a question about whether that should be prorated earnings or should it be the full year. If it's full year, it could be worth $0.02.

If it's prorated portion, it could be a $0.01. And so that's the only concern we have at this point.

But we, looking at our historical track record, are highly confident we can execute on realizing those customer savings and then realizing the benefits associated there with.

And we'll get clarity on that by September 30 in a final order from the Commission.

Is the test based on a cumulative amount or a run rate at a certain kind of a snapshot date?

It's a cumulative amount.

Okay. Thank you very much.

Thank you.

Good morning. Thank you.

Morning.

Morning Travis.

Hey you answered most of my questions. But I have one longer strategic one.

At what point do you look for landmarks for that extra $7 billion of CapEx?

So the key signpost that we would look for as we execute on our capital plan and potentially realize those upside opportunities and just to be clear what's in that. So to go from $18 billion to $25 billion, you really have a few pieces in there.

You've got gas infrastructure, which is just north of about $2.25 billion. And then you've got just under $750 million attributable to grid modernization and then potential Palisades replacement and the balance is really a potential replacement option for the MCV contract which expires in 2025 and that's about call it $3.5 billion or thereabouts if you include potential wind replacement coupled with gas peaker plant support.

And so as we think about what may allow us to pull those levers, it really is the historical constraints and that's customer affordability and/or the need to fund that an efficient way on our balance sheet. And so the signposts we'd need to see is how economic does wind become over time.

What cost savings are we able to realize to self-fund the business and again permit us to fund or execute on the capital plan of that magnitude? And, again, if the economics associated with renewables or other potential alternative means to replace that MCV PPA come into effect.

So it's a combination of I'd say affordability and balance sheet capacity in order to take that on.

Okay. And with that the Palisades replacement portion of it, is there any kind of indication that that might be out of the capital plan after the regulatory proceedings?

As Patti highlighted, we should have visibility by the end of September as to where we'll come out on Palisades. And then with respect to whether DIG or some other entity becomes being part of the longer term plan, we won't have visibility on that until we a file rate case in the subsequent year.

And then there's a bit of process that would need to take place. We'd need to get approval from the Commission for whatever purchase plan we have on the gas side.

Okay great. Appreciate it.

Thank you.

Thanks, Travis.

Yeah, thanks. Just maybe it's a little too early but following up on a question around the Palisades replacement and DIG.

Is that something that you would like to do or that's still a bucket of options that you're looking at?

I would call it in your words the bucket of options. You know the one thing that we want to make sure that we're doing is reducing and passing along the reduced cost to our customers and we think that's most important.

And you know, on one hand just on the question of DIG inside the utility or outside the utility we think it's a win either way. When it's outside of the utility, it's available to provide bilateral contracts and we think there's potential in that market.

If it's inside the utility, we think it can add value to utility customers. And so we feel very comfortable working through the alternatives and making sure that both the Commission and we are aligned and satisfied that we've got the resource adequacy for the State of Michigan, the visibility that we need for that resource adequacy and most importantly that we're able to pass along the savings as a result of the early termination of out-of-market PPA.

So we really are at the end of the day just going to look for the lowest cost method to backfill that PPA.

Okay. Thank you.

Yep.

Good morning.

Good morning, Jon.

Good morning.

Hey. Just a couple more details on the waterfall slide there kind of bridging the last six months of the year.

In terms of the rates and investment piece of the $0.07, are you assuming anything for the gas rates beyond what you've self-implemented today or just sticking with the $20 million?

As you know, historically, we've been very conservative around our accounting and expectations and so we've self-implemented $20 million and so that's where we're at.

Okay. Great.

That's helpful. And then, similarly for the Foundation spending, I think that was higher than normal in 2016.

Is the $0.05 delta that's kind of baked in here, does that assume any payments made in 2017 or is there still just kind of a normal year expectation on what you would spend on that?

Yeah. In our financial planning, we always presuppose that we'll make donations to the Foundation, but it's always a function of how well the business performs over the course of the first few quarters of the year.

And so we'll see where we're at by the fourth quarter and if we continue to trend well economically, we'd love to take advantage of those opportunities to put more money in the Foundation. Obviously, last year, the second half was quite good and so we really stepped up on the donations, not just the foundation, but for other opportunities of interest.

And as I've said before, if we see a soft or mild summer and we don't have those sorts of opportunities this year, we can clearly pull back on that sort of activity to meet our earnings guidance of $2.14 to $2.18.

So there could be some more room besides just the $0.05 that's baked on that side, theoretically?

Potentially, but that said, we're still focused on $2.14 to $2.18 and 6% to 8% growth.

Okay. Great.

Thanks a lot for taking my questions.

Thank you.

Thanks, Jon.

Thank you, Brandon. And thanks again for all of you for joining us this morning.

I'll just reiterate that we feel good about our performance in the first half in spite of the headwinds. While we are ahead of our plan and it's why we're reiterating our year end guidance of 6% to 8% EPS growth, as you know you can count on us to deliver.

And we definitely hope to see you September 25 at our Investor Day in New York. Thanks, Brandon.