BKH
#Thank you, <UNK>, and good morning, everyone.
I will be starting my comments on Slide 3 of the webcast deck for those of you following along.
We'll have a format similar to past quarters.
I will give a quick update on the quarter.
Rich <UNK>, our CFO, will give the financial update for the quarter.
I'll cover forward strategy, and then we'll address questions.
You may have noticed, or will notice as we go through the process this morning, that we've made a few changes to our presentation format.
Notably, we've added some more detail to our forecasted capital spending, which should improve some visibility into our future earnings growth.
We expect to further enhance those disclosures as the year progresses.
Moving on to Slide 5, first quarter 2018 highlights for our utilities.
On the 25th of April, our Colorado Electric utility received approval from the PUC in Colorado to contract with our own IPP subsidiary, Black Hills Generation, to purchase 60 megawatts of wind energy through a 25-year power purchase agreement.
That agreement will provide the final amount of renewable resource we need to meet the state's renewable energy standard of 30% by the year 2020.
On April 26, Rocky Mountain Natural Gas, which is our intrastate gas pipeline in Colorado, received a recommended decision from the Colorado Administrative Law Judge, approving a settlement for the rate review it filed in October of last year.
That settlement, which is subject to final approval from the Colorado PUC, includes: a $1.1 million increase in annual revenue; importantly, an extension of our safety, system and integrity rider to cover investments that will be made this year through 2021; it includes an authorized return on equity of 9.9%; and a capital structure that's 46.6% equity.
We expect new rates to be effective June 1, again, pending final approval from the commission.
Moving on to Slide 6, continuing with utilities highlights.
During the quarter, our South Dakota Electric utility commenced construction on a $70 million, 175-mile transmission line from Rapid City, South Dakota, to Stegall, Nebraska.
That project will be constructed in 2 segments.
The first should be placed in service by the end of this year and the second segment by the end of 2019.
Also during the quarter, we continued our efforts to simplify our utility organizational structure by restructuring several of the legal entities that we acquired in 2016 through the SourceGas acquisition.
That restructuring resulted in a $49 million tax benefit associated with goodwill that is now amortizable for tax purposes.
Highlights for our Power Generation segment for the quarter.
I already noted on April 25, our electric generation subsidiary was selected to provide 60 megawatts of wind to our Colorado Electric utility.
That $71 million Busch Ranch II wind project should be constructed and in service prior to the end of 2019.
Moving on to Slide 7, corporate highlights for the quarter.
On April 23, our board declared a quarterly dividend of $0.475 a share, which is equivalent to an annual dividend rate of $1.90 per share.
That $1.90 per share equivalent rate represents our 48th consecutive annual dividend increase.
On March 8, S&P affirmed its corporate credit rating for Black Hills Corporation at BBB flat, but revised its outlook to positive from stable, which we found encouraging.
Finally, related to discontinued operations, which is our Oil and Gas segment.
As of yesterday, we'd executed agreements to sell ---+ or had closed on sales transactions for about 96% of our oil and gas properties, as measured by gross well count.
Now we expect to sell our remaining assets prior to the end of the quarter.
Slide 8 provides a reconciliation of first quarter, net income from continuing operations as adjusted compared to the first quarter of 2017.
The most notable change being improved performance at our Gas Utilities.
Rich will provide more detail in his financial update, which I'll turn it over to Rich to cover financials.
Very good.
Thanks, <UNK>, and good morning, everyone.
As <UNK> touched on, we delivered solid first quarter financial performance.
With help from favorable weather, year-over-year, our natural gas utilities delivered strong financial results in Q1, demonstrating the benefits of our diversified utility portfolio and the 2016 SourceGas acquisition.
I'll jump in on Slide 10, where we reconciled GAAP earnings to earnings as adjusted, a non-GAAP measure.
We do this to isolate special items and communicate earnings to better represent our ongoing performance.
This slide displays the last 5 quarters and trailing 12 months as of March 31, 2018 and 2017.
As detailed on the slide, we experienced special items not reflective of our ongoing performance in each of the past 5 quarters.
The first special item is acquisition-related expenses associated with the SourceGas acquisition and integration.
We completed our integration work in 2017 and don't have that adjustment in 2018 or forward.
The second special item relates to income taxes and is predominantly the result of federal income tax reform.
The corporate tax rate change from 35% to 21% beginning in 2018 required a revaluation of our deferred asset ---+ deferred tax assets and liabilities on December 31, 2017, resulting in a $0.21 EPS benefit in the fourth quarter of 2017.
Given additional information in Q1, certain estimates impacting the revaluation have been updated, resulting in a Q1 charge of $2.3 million or $0.04 of EPS.
The largest special item in Q1 2018, also related to income taxes.
As <UNK> noted, as part of our effort to simplify our legal organization, in Q1, we restructured certain entities as part of the 2016 SourceGas acquisition.
The restructuring increased goodwill that is amortizable for tax purposes, resulting in an associated deferred tax benefit of $49 million or $0.91 of EPS.
These items are not indicative of our ongoing performance and, accordingly, we reflect them on an as-adjusted basis.
Our first quarter as-adjusted EPS was $1.63 compared to $1.44 for the first quarter last year.
The earnings uplift comparing Q1 this year to Q1 last year was primarily driven by a colder winter heating season at our Gas and Electric Utilities compared to a mild winter last year.
We estimate mild weather last year, as compared to normal, negatively impacted Q1 2017 EPS by $0.09.
This year, we estimate that colder weather, compared to normal, positively impacted Q1 2018 EPS by $0.05.
Slide 11 is a new slide we've added to our investor materials to provide additional transparency related to year-over-year comparisons.
The waterfall chart illustrates major drivers that comprise the differences from Q1 2017 to Q1 2018.
All amounts on the chart are net of tax.
Again, you'll note weather was a large positive driver year-over-year, especially at the Gas Utilities.
We recorded a revenue reserve in Q1 2018 at the Gas and Electric Utilities due to tax reform as we expect to pass the benefit of the lower corporate tax rate on to customers through reduced bills.
However, this has no impact on net earnings due to the lower income tax rate as a result of tax reform.
<UNK> will touch on this more in a bit, but in short, we continue to work with our regulators in each of our states to pass the tax benefit from tax reform to our utility customers.
You can also see we did a good job managing O&M on a consolidated basis, with limited O&M increases year-over-year.
Slide 12 displays our first quarter income statement.
Gross margin was flat year-over-year despite the revenue reduction related to tax reform that I noted a moment ago.
Operating expenses and DD&A increased modestly comparing Q1 2018 to Q1 2017, primarily due to typical operating expense increases and incremental plant investments.
Operating income was down for the quarter compared to the prior year, again, mainly due to revenue reserves related to tax reform, which is offset by reduced income tax expense below the operating income line.
Moving below the operating income line.
Interest expense increased slightly year-over-year due to higher interest rates on our variable-rate short-term debt.
The most significant change, comparing Q1 2018 to Q1 2017, is on the income tax line.
You'll note the $26 million income tax benefit recorded in Q1 2018 despite $113 million of pretax income.
This resulted from the legal reorganization we mentioned already.
The effective tax rate, after adjusting out the special items I noted on Slide 10, is 18.9% in Q1 2018 compared to 29.6% in Q1 2017.
The lower effective rate this year was driven by tax reforms corporate rate reduction.
Moving to the as-adjusted income from continuing operations line, we generated $88 million for the quarter compared to $79 million for the same quarter last year, a 12% increase.
You'll note our Q1 2018 diluted share count decreased compared to Q1 2017.
This was due to the application of the treasury stock method related to the unit mandatory securities we issued in late 2015 to help fund the SourceGas acquisition.
Until these securities convert to equity in November of this year, we're required to apply the treasury method of accounting, whereby we include a portion of the shares in our diluted share count.
The number of shares we include is based on the average daily closing price of our stock during the reporting period.
Our average share price was lower in Q1 2018 compared to Q1 2017.
So in Q1 2018, we added approximately 700,000 shares to our diluted share count, compared to approximately 1.6 million additional shares in Q1 2017.
As I noted in our year-end earnings call on February 2, we're assuming approximately 56 million weighted average shares in our full year 2018 guidance, as we will have approximately 60 million diluted shares beginning November 1, after the conversion occurs.
Considering the increase in as-adjusted net income and reduced share count, as-adjusted EPS grew $0.19 or 13% from the same quarter last year.
I'll now discuss each business segment.
Slide 13 compares our Electric and Gas Utility segment's Q1 2018 gross margin and operating income compared to Q1 2017.
Our Electric Utilities operating income decreased $7.3 million in the first quarter of 2018 compared to first quarter 2017.
Electric Utilities gross margin decreased $1.4 million quarter-over-quarter, driven by a $6.1 million revenue reserve related to tax reform, partially offset by higher margins from investments in transmission, favorable weather and higher non-energy revenues.
Operating expenses, including depreciation, were $5.9 million higher for the first quarter of 2018 compared to the first quarter of 2017, as a result of increased vegetation management and outage-related expenses as well as increased property taxes and depreciation associated with rate base investments.
Moving to the right slide of Slide 13.
Our Gas Utilities reported an increase of $3.4 million in operating income comparing Q1 2018 to Q1 2017.
Gross margins were favorable by $4.2 million quarter-over-quarter, as cold weather added $9 million of incremental margin year-over-year.
Heating degree days were 2% higher than normal in Q1 2018 compared to 13% below normal for Q1 2017.
Customer growth and capital recovery rider mechanisms added approximately $4 million to margins year-over-year.
These increases were partially offset by tax reform-related revenue reserves of $9 million.
Operating expenses were nominally higher compared to the prior year, reflecting strong cost management of the Gas Utilities.
As I noted earlier, the unfavorable impact of operating income ---+ to operating income from tax reform at both the Electric and Gas Utilities is offset by lower income tax expense and is earnings neutral.
On Slide 14, you see that Power Generation operating income increased $400,000 comparing Q1 2018 to Q1 2017, primarily from reduced sales volume under our power purchase agreements.
The Power Generation segment continued to realize strong contract availability from its generating units and continued its strong earnings and cash flow contributions.
Also on Slide 14, you'll see in the first quarter of 2018, our Mining segment had a $1 million operating income increase compared to first quarter 2017.
For the quarter, revenue was $600,000 higher, primarily from higher tons sold in 2018.
On the O&M side, we decreased cost by $400,000.
Our mine continues to perform at a high level, with sales almost entirely to on-site [9-mile plants] and roughly half our sales based on a cost-plus pricing methodology.
Slide 15 shows our capitalization.
At March 31, our net debt-to-capitalization ratio was 64.1%, a decrease of 190 basis points from year-end.
This reduction was driven by the increase in retained earnings due to our solid first quarter earnings as well as by strong first quarter cash flows that allowed us to reduce our total debt from year-end.
Our $299 million of unit mandatory securities are reflected as debt on our balance sheet until the units convert to equity on November 1 this year.
After conversion, we expect our debt ---+ net debt-to-capitalization ratio to decline below 60%.
While we may need to increase our short-term borrowings from time-to-time over the course of 2018 and 2019 to fund our currently forecasted capital expenditures, we don't anticipate the need to issue any equity to fund these activities.
If additional capital investment opportunities emerge, we have our At-the-Market equity program available if the need to issue any equity arises.
Slide 16 shows our debt maturity schedule.
The unit mandatories require us to remarket the debt noted as a 2028 maturity on the schedule, which we will do during the second half of this year.
We're also evaluating options for the 2019 and 2020 maturities.
Slide 17 shows our investment-grade credit rating.
As <UNK> noted, during the first quarter, S&P affirmed our BBB credit rating and upgraded the outlook to positive.
We're committed to maintaining our strong investment-grade credit ratings, and our forward forecasted metrics support those ratings.
On Slide 18, we're reaffirming our 2018 earnings guidance of $3.30 to $3.50 per share based on the assumptions previously provided on February 2, 2018.
I'll turn it back to <UNK> now for his strategic overview.
All right.
Thank you, Rich.
Moving on to Slide 20.
We group our strategic goals into 4 major categories: profitable growth, valued service, better every day and great workplace, with the overall objective of being an industry leader in all we do.
On Slide 21.
From a strategy execution perspective, we're focused on delivering strong long-term total shareholder returns.
We plan to accomplish that by achieving a long-term EPS growth rate that's above the industry average, targeting a 50% to 60% dividend payout ratio, while still retaining the flexibility to increase that dividend during periods of slower EPS growth and continuing our track record of 48 consecutive annual dividend increases.
On Slide 22.
We're currently in the process of transitioning our earnings growth drivers, from a largely acquisition- and integration-focused strategy over the last year or so with the SourceGas acquisition, back to a more traditional utility growth approach.
In the near term, this year and next year, we expect slower earnings growth since we're entering test years in preparation for rate review filings or actually commencing those rate review filings in some of our jurisdictions.
We do have 3 active rate review processes currently in process right now.
Over the long term, starting in 2020 and beyond, we expect higher earnings growth expectations, driven by strong capital investments to meet our customer needs, continued focus on standardization and efficiency improvements and back to more regular rate review filings.
Slide 23.
As we focus on delivering long-term shareholder value, our fuel and service territory diversity reduces our business risk and drives more predictable earnings.
Slide 24.
Our utility acquisitions over the years have created a much larger transmission and distribution system network, both on the electric and the gas side of the business.
With that increase in size comes increased opportunity for investment to serve a much larger customer base.
Moving on to Slide 25.
Strong capital spending has in the past and will continue to drive much of our earnings growth.
We plan to invest almost $2.3 billion over the next 5 years to better serve our 1.25 million utility customers.
And that level of investment far exceeds depreciation contributing to earnings growth.
Slide 26, which is a new look, provides a detailed capital spending forecast for our Gas Utilities, including breakouts by state, investment type and recovery mechanisms for a full 5 years compared to the 3 years that we previously disclosed.
Slide 27 provides a similar capital spending detail for our Electric Utilities.
Moving on to Slide 28.
This slide provides a regulatory update for our utilities, highlighting the status of our active rate review filings and our federal income tax reform dockets by state.
You'll notice that we've completed the process of determining customer benefits for federal income tax reform in both Iowa and Kansas, and either have started to reflect those changes on customer bills, as is the case in Iowa, or are planning to beginning in ---+ or Kansas, I'm sorry, and then planning to do that beginning in July for the state of Iowa.
I've already noted the other key regulatory updates, with one exception.
And that is on April 30, we received an order from the Denver District Court regarding our appeal of the Colorado Public Utility Commission's prior decision on our 2016 rate review for Colorado Electric.
There are several issues addressed in the ruling, some positive and some negative for Black Hills.
Most notably, we're very disappointed that the court affirmed the commission's decision related to the rate treatment of the new gas turbine generator we constructed in Colorado.
The PUC in that 2016 rate decision assigned a lower return on investment for that turbine than for any of our other utility assets in Colorado.
The turbine was built in response to the Colorado Clean Air-Clean Jobs Act, a law passed in Colorado that was intended to provide an incentive to utilities to retire their coal fire generation before the end of its useful life and replace it with cleaner, more modern generation.
Now for the commission to assign a lower return on investment for the new generation, after we built it in good faith and in compliance with the Clean Air-Clean Jobs Act, this is very troubling, and the fact that the court upheld that is even more troubling.
And frankly, we feel it's contrary to the intent of the Colorado Clean Air-Clean Jobs Act.
We're currently evaluating the impacts of the court order on our business and considering our next steps in the legal process.
Moving on to Slide 29.
Now we're extremely proud of our track record of annual dividend increases that I mentioned earlier, including stronger increases the past several years, reflecting our confidence in strong future earnings growth and cash flows.
As I noted earlier, we have the flexibility to use larger dividend increases during periods of slower earnings growth to help deliver solid total shareholder returns.
Even after relatively strong dividend increases during the past few years, we're still well within our targeted 50% to 60% dividend payout ratio range.
Moving on to Slide 30.
Now we focus every day on operational excellence.
We continue to make great progress, improving our safety performance, and also continued to consistently demonstrate our power plant availabilities, which are among some of the best in the industry.
On Slide 31, we note that we've created a new corporate responsibility report, which is available on our website.
We encourage you to check that out.
And finally, on Slide 32.
This is our scorecard for 2018.
This is our way of holding ourselves accountable to you, our shareholders, for our accomplishments in our key strategic objectives.
Now that concludes our remarks.
We'd be happy to entertain any questions.
Yes.
I would categorize this one.
Obviously, this is an investment from our IPP subsidiary.
I would categorize the earnings from that as probably consistent with how you would look at an IPP project, that is, it's financed with a little more debt than you would expect from a utility capital structure.
And then also, the returns would be consistent with an IPP-like return.
As far as whether we would do this outside of our existing service territories, they're not ---+ I would say, the answer is yes, but on a limited basis.
I think there would have to be a very compelling strategic reason for us to do so, whether that's a relationship with an existing wholesale customer or something like that.
We don't have any aspirations of running out and being a full-blown competitor in the IPP business.
That's not our strength.
But I do think there are certain circumstances where it may make sense for us to do this to for others.
They will be fairly few and far between, however.
Well, I think the return would be probably comparable, but the capital structure's significantly different with less equity, right.
And then as ---+ consistent with wind projects and other renewable projects, a lot of the earnings are really driven by production tax credits, so they show up below the operating income line.
And I'd add one thing to that, <UNK>.
That was a competitive process, and there were a lot of bids.
It was vigorously competitive so we did have to be aggressive to win that bid.
Yes.
From Q1 to Q2, you can see the difference in our CapEx schedule is the additional wind project.
We added $11 million to this year's capital and $60 million the next year.
We're still comfortable that after the convert, we're going to be well below 60%.
When that converts, that'll get our debt-to-total cap down below 60%, and our cash flow should keep us there through the end of 2019.
And then if you look post 2019 at that CapEx schedule, we should remain comfortably there.
If additional large projects come up, we may need to issue some equity.
That's where I'd leave that, <UNK>.
Yes.
And I'd say that story is consistent with what we've talked about in the past, <UNK>.
We've said we have fairly aggressive capital spending outlook going forward, but we expect to finance that with internal cash flows and debt, absent any big special projects that might get added.
And that is why we have kept our At-the-Market equity issuance program active, just in case we may have one of those projects.
But we would only use that in the event that we'd have some additional CapEx that is not on our current schedule.
Well, there are several in the works, but not mature enough to the point that we're ready to talk about specific projects.
I mean, we're always looking at some renewable projects for our Electric Utilities, pipelines for our Gas Utilities, transmission lines we've talked about, things like that.
And we have several of those that we're looking at and studying and, potentially, would integrate into our forward plans, just not mature enough to actually file a certificate of public convenience in necessity or something that would say we're really ready to propose yet.
Yes.
We've got several options and we're evaluating all those.
One is, of course, another level of appeal, which we certainly could do.
The other one is we could basically elect to either go back and ask the commission to rehear that or frankly, include it in another rate case.
All those options are on the table.
And frankly, having just received that ruling earlier this week, we're still in the process of discussing what those options are and which ones would be the best to pursue at this point in time.
But they're all on the table.
It's really hard to say and hard to speculate.
I think we've been pleased working in relationship with the commission recently and we hope that continues.
Well, they're all in various states of process.
So the Colorado Rocky Mountain Natural Gas pipeline, that settlement includes the impacts of tax reform.
Our active rate reviews in Northwest Wyoming and in Arkansas, when they get completed, will include the results of tax reform.
And then all of the others are at various stages in the process, from very early to well underway.
Our tact in most of those ---+ and it's going to be a commission-dependent decision state-by-state, but we've taken the position that we think it's best for customers to go back to their most recent rate case and just compute the difference on the tax rate and start collecting ---+ or stop collecting that difference from customers going forward and, of course, refund it back to the effective date of the tax rate change.
That's not going to happen in every state, we don't think.
Some of them are asking us to look at what's the current impact rather than the impact back to the most previous rate case.
But all are progressing, and we're comfortable and happy, frankly, with the progress we're making.
Some will be a little slower, though.
All right.
Thank you.
Well, thanks for your time and attention this morning, everyone.
We appreciate you attending our Q1 earnings call.
And for those of you who are going to be at the AGA Financial Forum, we look forward to visiting with you there.
Have a great day and a great weekend.
