Idacorp Inc (IDA) 2012 Q1 法說會逐字稿

Good day, and welcome everyone to IDACORP First Quarter 2012 Conference Call. Today's call is being recorded and webcast live. A complete replay will also be available from the end of the day for a period of 12 months on the company's website at www.idacorpinc.com.

(Operator Instructions)

At this time I'd like to turn the call over the Directory of Investor Relations, Mr. Lawrence Spencer. Please go ahead Sir.

Thank you, Deana, and good afternoon everyone. Welcome to our First Quarter 2012 Earnings Release Conference Call. We issued our earnings release before the markets opened today, and that document, along with our SEC Form 10-Q, is now posted to our IDACORP website at www.idacorpinc.com.

We will be using a few slides to supplement today's call, and these are also located on our IDACORP website. We will refer to specific slide numbers as we work our way through today's presentation.

Now moving to slide 2. On the call today, we have LaMont Keen, IDACORP President and Chief Executive Officer, Darrel Anderson, Idaho Power President and Chief Financial Officer, and Steve Keen, Idaho Power Senior Vice President Finance and Treasurer. We also have other individuals available to help answer questions during the Q&A period.

Before turning the presentation over to Darrel, I'll cover a few details with you. First, our Safe Harbor Statement is on slide 3. Our presentation today contains forward-looking statements, and it is important to note that the company's future results could differ materially from those discussed. While these forward-looking statements represent our current judgment of what the future holds, these statements are also subject to risks and uncertainties that may cause actual results to differ materially from statements being made today.

As a result, we caution you against placing undue reliance on these forward-looking statements, which reflect our opinion only as of today. A discussion of factors that could cause future results to differ materially can be found in slide 3, and in our filings with the Securities and Exchange Commission, which we encourage you to review.

Referring to slide 4, I'll briefly discuss the financial results from today's earnings press release. First quarter 2012 net income attributable to IDACORP was $24.9 million, $4.8 million less than last year's first quarter.

Idaho Power's first quarter 2012 net income was $25.8 million, $4.0 million less than the first quarter of 2011. Notably, the first quarter of 2011 included the use of $3.0 million more in additional accumulated deferred investment tax credits than the first quarter this year.

Importantly, as indicated in today's earnings press release, based on these results, we are reaffirming our current full-year 2012 IDACORP earnings guidance in the range from $3.00 to $3.15 per diluted share.

I'll now turn the presentation over to Darrel to discuss other key drivers for the first quarter, and review our key operating and financial metrics.

Thanks, Larry, and good afternoon. We're changing the order of today's call a little bit from previous calls. I will begin by reviewing the results for the quarter, and update you on key operating and financial metrics. Steve Keen will then discuss our liquidity and financing activities for 2012, and LaMont Keen will wrap things up by providing an update on our Langley Gulch natural gas-fired facility, and other business-related matters. We will then stand for your questions.

On slide 5, we present a reconciliation of net income attributable to IDACORP from the first quarter 2011 to the same period in 2012. This reflects a decrease in net income of $4.8 million. The full reconciliation table is included in the Form 10-Q we filed this morning.

Operating income was positively impacted by $5.1 million due to base rate changes, pension expense recovery, and changes in power supply costs, net of the related power costs and fixed costs adjustment mechanisms.

However, warmer than normal temperatures during the first quarter of 2012, compared to 2011, contributed to a $2.8 million decline in operating revenues from last year's first quarter. Heating degree days were 10% lower than last year, and 13% less than normal, which contributed to the reduction in operating revenues for the quarter.

Operations and maintenance expenses increased $7.8 million over first quarter 2011. The increases were attributable to increased pension expense of $3.0 million, concurrent with increased recovery of deferred pension costs and rates, labor and related expenses of $2.3 million, and $2.4 million in expenses primarily related to our Smart Grid program.

The quarter included a smaller amount of additional accumulated deferred investment tax credits, or ADITC, versus last year of approximately $3.0 million, which directly reduced earning. Offsetting these reductions, were increased earnings at Bridger Coal Company of $3.4 million, and an increase in allowance for funds used during construction of $3.0 million, in part related to capital expenditures to date at the Langley Gulch power plant.

Next, I'll provide a brief reminder on the mechanics of the ADITC extension in the Idaho jurisdiction, which we discussed in more detail on our 2011 earnings call in February. Please refer to slide 6.

A December 2011 settlement stipulation with the Idaho Public Utilities Commission provides that if Idaho Power's Idaho jurisdictional return on earned equity for 2012, 2013, or 2014 is less than 9.5%, then Idaho Power may use additional ADITC amortization to help achieve a minimum 9.5% return on year-end Idaho jurisdictional equity in the applicable year.

You can see that earnings above 10% are shared between our Idaho customers and Idaho Power with the amount shared dependent on the actual Idaho return on year-end equity. The amount of additional ADITC recorded is based on the estimated amount of Idaho jurisdictional earnings projected for the full year, and the difference, if any that is less than a 9.5% return on equity, is evenly divided among the quarters.

While influenced by a number of factors, we currently estimate that ADITC utilization will be less than $5.0 million for 2012. The total amount of ADITC available for 2012 is $25.0 million.

As indicated on slide 7, we see no changes in our key operating and financial metrics guidance we reviewed with you previously in February. The estimated hydroelectric generation range of 7.5 million to 9.5 million megawatt hours is based on March 31, 2012 reservoir storage levels, and forecasted weather conditions.

The annual median hydroelectric generation is 8.6 million megawatt hours. Based on these assumptions, and taking into our account our settlement stipulation with the Idaho Public Utilities Commission, we are able to reaffirm our 2012 full-year IDACORP earnings per share guidance in the range of $3.00 to $3.15 per diluted share.

As discussed in our 2011 10-K and in our the 10-Q we filed today, our earnings results are seasonal, in that utility revenues and expenses are not incurred evenly during the year. Our tiered rate structure has impacted earnings recognition between quarters, as revenues during higher use periods may be influenced by higher seasonal rate.

The earnings range assumes that the Langley Gulch power plant is commercially available as of July 1, 2012, and we are earning a return on the plant commencing on that date. This also includes an estimated use of additional ADITC amortization of less that $5.0 million in 2012.

In addition to the Langley Gulch filing, we have continued to be active on the regulatory front. On slide 8, we have included a list of some key pending Idaho and Oregon regulatory matters, and their estimated annualized revenue impact.

We had other rate changes approved or that went into effect earlier this year which are not shown on the slide, most notably, an Idaho base rate increase of $34.0 million and a rate decrease of $10.6 million associated with removal of depreciation of non-AMI meters.

Steve will now discuss IDACORP's 2012 liquidity position, and the 2012 expected debt and equity financing requirements.

Thanks, Darrel. I will begin with the discussion on cash flows for the quarter, discuss briefly our liquidity position, then conclude with our recent financing actions, and a look ahead at future financing needs. Slide 9 includes a portion of this information.

IDACORP's cash flow from operations for the first quarter of 2012 was $37.7 million, a decrease of $55.5 million from first quarter 2011. The reduction was largely due to $34.0 million in pension plan contributions in the first quarter of this year, whereas no contributions were made in the first quarter last year.

Also, IDACORP had net income tax payments of $0.2 million this year, compared with net refunds of nearly $13 million in last year's first quarter. And finally, changes in regulatory assets associated with the Idaho and Oregon power cost adjustment mechanisms reduced cash flows by $22.0 million.

IDACORP and Idaho Power currently have $125 million and $300 million in credit facilities, respectively, which are available until the termination date on October 26, 2016. Commercial paper outstanding at IDACORP as of March 31, 2012 was $61.5 million compared to $54.2 million at December 31, 2011. Idaho Power had $1.5 million of commercial outstanding as of March 31, 2012, and none outstanding at the end of 2011.

Modest cash balances at both IDACORP and Idaho Power leave us with $69.4 million and $301.5 million, respectively, in available liquidity.

Also, as of March 31, 2012, there were 3 million IDACORP common shares available for issuance under our continuous equity program, with none issued during the first quarter of this year.

On April 13, 2012, Idaho Power issued $150 million in principal amount of first-mortgage bonds, equally divided in two tranches of 10- and 30-year bonds. The 10-year bonds were issued with a 2.95% coupon rate, and the 30-year bonds were issued with a 4.3% coupon rate. In April, Idaho Power issued a notice to redeem, prior to maturity, its $100 million in principal amount of 4.75% first-mortgage bonds due November 2012.

Idaho Power intends to use a portion of the net proceeds from the April issuance to effect the redemption. We expect the redemption will be effective in May of this year. The remaining net proceeds will be used to fund a portion of our capital requirements.

For the remainder of 2012, we expect minimal need for external financing at both IDACORP and Idaho Power, other than issuance of IDACORP common stock, and of the dividend reinvestment and employee-related plans. While we believe it is unlikely at this point, IDACORP may also decide to issue common stock from time-to-time under its continuous equity program, depending on market conditions and capital needs.

We continue to target an approximate mix of 50% equity and 50% debt in our capital structure. As of March 31, 2012, IDACORP's capital structure consisted of 52% equity and 48% debt, indicating a reduced need for additional equity. For the remainder of 2012, we will continue to focus on controlling costs, generating sufficient cash from operations to meet operating needs, and contribute to capital expenditure requirements.

Now, I'll turn the discussion to LaMont where he will update you on our Langley Gulch power plant and other business matters.

Thanks, Steve, and good afternoon everyone. In early April, we conducted a successful first fire of the 300 megawatt natural gas-fired Langley Gulch power plant. This began the final stage of testing for our newest power generation resource. On slide 10, we present some details about the Langley Gulch plan.

We have requested recovery of the $60 million annual Langley Gulch revenue requirement in the Idaho jurisdiction to be effective July 1 to coincide with the power plant's in-service date, and the $3 million annual increase required in the Oregon jurisdiction with a less certain effective date, though the Oregon Commission schedule provides for the new rates effective March 2013. We anticipate the plant will be ready to serve customers this summer, when demand on Idaho Power system is at its highest.

Our two major transmission projects, the 1,150 mile Gateway West, and the 300 mile Boardman to Hemingway project continue to move forward. We are working with the Federal Rapid Response Transmission Team, created last year to expedite environmental reviews in permitting, consolidate decision making, and streamline and consolidate the myriad of legal, regulatory, and other hurdles that inevitably arise from these proceedings.

With regard to a separate regulatory matter, in March Idaho Power filed an application with the IPUC seeking a temporary stay of its obligation to enter into new power purchase agreements with Public Utility Regulatory Policies Act, or PURPA, power producers.

And while the IPUC denied Idaho Power's request for a stay in a March 22 order, the IPUC initiated interim protection for our customers. The IPUC provided that it would individually evaluate all contracts for PURPA projects over 100 kilowatts entered into by Idaho Power and presented to the IPUC for approval.

The IPUC noted that Federal Energy Regulatory Commissions regulations require that the purchase price under PURPA contracts be just and reasonable to customers, and in the public interest. The contracts are to be evaluated under that standard.

In regard to our service territory, 2012 has delivered some positive moves. According to the Idaho Department of Labor, unemployment in Idaho has now dipped below 8%. We have previously mentioned the location of a new production facility in southern Idaho by the yogurt producer, Chobani. This last month has also brought an announcement that Central Garden and Pet Company will establish a new shared-services center in Boise, bringing with it a number of professional level jobs.

Our low energy prices contribute to making our service territory an attractive location for business and residential customers. Our general business customers increased 4,087 customers from the first quarter of 2011 to the first quarter of 2012, compared with 2,467, and 2,651 in the last two years first quarter comparisons. This indicates signs of economic recovery.

In the first quarter, we also renegotiated our existing contract with Hoku as the timing of its whole production ramp up was delayed. The revisions to the Hoku contract were conducted with Idaho Power, Hoku, and IPUC staff participation, and the result was a lower cash requirement in the near-term, with a correlative increase to later payments. From Idaho Power's perspective, our earnings expectations in 2012 were preserved in this renegotiation.

Under the revised agreement with Hoku, we expect to recognize approximately $5.4 million in full-year 2012 revenues associated with the portion of contract payments that are not effected by the Idaho PCA. We also expect to recognize an additional $0.3 million in PCA pre-tax earnings benefit.

And finally, I am pleased to share that Idaho Power tied for highest customer satisfaction in the West Mid-Size Segment in the JD Power 2012 Electric Utility Business Customer Satisfaction Study. We tied with two other utilities with the third score among all 95 utilities in the study. This is welcome recognition of our ongoing customer focus and commitment to business excellence.

This concludes my update, and now would like to respond to your questions.

Thank you. Ladies and gentlemen we will now begin the question and answer session. (Operator Instructions). And the first question will come from Paul Ridzon, KeyBanc.

Good afternoon, guys.

Hi, Paul.

Could you touch a little more on the seasonality of rates? Is this a volumetric phenomena with higher rates, or is there some rate design, with higher summer rates that's going to multiply as volume is up?

Paul, this is Darrel. I'll start it off and we'll see where it goes from here. But you remember we have seasonal rates in place that kick into effect in June, July, and August. They go for that three-month period during our heavy-load period. And so, it's a three-tiered structure, which basically goes the higher -- the more usage you have the higher the rate, it ends up being.

And so, there is a volumetric component to it, as well as a price component to it. And so, if you look historically at the last two years, arguably, that the third quarter has historically been our largest earnings quarter.

When you go back and look at history, because if it were seasonal use hits for us, and then obviously the shoulder period, which generally this first quarter is one of those periods, and then you take a look, it depends on what happens in the second quarter, because we could see that effect of those higher rates in June with our irrigation load and cooling load coming on in June, depending on what happens with weather.

I want to clarify what you said about Hoku. You don't expect any earnings impact in 2010.

Well, what we said is, we've attempted to protect the company's benefit under that agreement, and so what we have disclosed, really, is what we expect to be the amount of revenue we would recognize in the current year.

If they don't pay, then yes, we could be impacted, but under the assumption that they continue to pay under the agreement, we've protected the company in the extension of the agreement. What we did was share with you the quantification of what that revenue impact is expected to be.

In worse case, I guess you could dip into ADITC's if necessary.

That's correct.

Thank you very much.

And the next question comes from Brian Russo, Ladenburg Thalmann.

Good afternoon.

Hi, Brian.

Could you just remind us of your dividend policy, please?

LaMont will talk to you about that, Brian.

Certainly, and again, it's laid out in the 10-Q on page 51, similar as it was into our 10-K for the year that the board established a dividend policy of 50% to 60% payout over a time frame going forward, with the usual qualifying factors with regard to timing of that, and other economic and regulatory considerations we would have on our system.

So, we are proceeding with that. We increased the dividend in January. The board reviews that on an ongoing basis, and the expectation is, over time, we will progress toward the goal that the board set.

Any possibility of a second increase in 2012, or is this kind of like an annual increase type of profile?

The board hasn't said anything that says whether it's going to be review more than once, or only annually. So, I have to say its their discretion, and it's viewed on an ongoing basis, as I said last quarter. It's probably not unreasonable to anticipate some kind of at least an annual review with regard to that, since we've established the policy, but they're not bound by that.

They can look at it at a period of time, and that the thing I'd note now, as you notice, we have rate requests in in Idaho and Oregon for considerable amount that the regulators are going to be deciding on over the next two or three months. Obviously, I think at this point it's prudent to verify that those things are approved as requested, or nearly so.

So, having that behind us sometime later in the year, then it's board discretion whether they wait until the first of next year to do something.

Okay, understood. Remind me, what is the ADITC balance, the total balance on the books?

I think, Brian, it would probably -- it's $70 millions plus, maybe, I don't know that I have the number off the top of my head, but $70 million-plus, in that range. And, as you know, under our current agreement we have up to $45 million available to us over this 3-year period.

Okay. And they don't expire, right?

Brian, this is Steve. They don't expire, but there is an amortization of that amount on an annual basis. So, they do decline a little bit, regardless of whether use any additional amounts or not. But it's a fairly long amortization period over the life of the plan. So, it's kind of a slow run.

Could you give us an idea of what your year-end 2012 rate base will look like, or at least year-end 2011 rate base actual?

Brian, we don't actually have that. I mean, I think the -- we make some reference -- I'm trying to think. We have some disclosures in the 10-Q about our overarching rate base in Idaho, and where we talked about -- on page 52 of the Q we talk a little bit about what our Idaho jurisdictional rate base was at the end of December, which is 2 point -- in that case 2.36 billion. But I don't have any further break out of that handy with us today.

Okay. But you say 2.36 billion as of December 2011.

Right.

Okay.

And that's Idaho jurisdictional component.

Okay. And then, lastly, I think the Boardman-Hemingway line is supposed to be operational in 2016. Is that time line still realistic?

I'm going to have Vern Porter, who leads our transmission effort there, and has spent a lot of time with this area. We'll have Vern just talk a little bit about the -- what's coming up with respect to Boardman-Hemingway.

Thanks, Darrel. Well, as we laid out in the Q, the 2011 Integrated Resource plan calls for a 2016 in-service date, and that would bring some immediate reliability relief to us benefits, but the actual date is actually going to depend on permitting and regulatory approvals, of course, and also the needs of our partners.

We announced earlier this year that we're partnering with PacifiCorp and Bonneville Power on the permitting of this project. And so, as we move forward into the 2013 Integrated Resource planning, we'll be taking a close look at that in-service date, and having further discussions with our partners, and if there is a change, we'll get that information posted, and I'll let you know.

I guess if the transmission line gets delayed, will you run into reliability problems in 2016.

No, we won't. We will, in our Integrated Resource planning, we'll take that into account and take necessary measures to ensure we have reliability.

Right. So, if there is no transmission line, would you need to build a CCGT?

Brian, this is Darrel. I think one of the things to think about is, again, as we gear up for this next IRP, we'll be looking at all those alternatives, and as you know -- I mean, we can look at a number of different options, in order to meet those needs. One of those could be a new peaker plant, could be a combined cycle plant. As you know, we did build Langley such that it's expandable out there. The footprint there is such that we could expand it.

And we would just look at a lot of different options as, again, as part of this IRP, if we don't believe we can hit that 2016 date. And so, there will be a number of options on the table. But we, again, we will almost have to kind of value each of those, and see which is the more appropriate path.

Thank you very much.

Thanks, Brian.

And the next question comes from Sarah Akers, Wells Fargo.

Hey, good afternoon.

Hi, Sarah.

Question on the $5.4 million of pre-tax revenues that Hoku's driving -- that you would expect to collect from Hoku in 2012. Has any of that been received so far?

You know Sarah, we're reluctant to comment too much on individual customer activity, but I will say to date they are receiving service, and the only way they would continue to receive service is as long as they're current on their payment.

Okay. And then, if they were no longer receiving service, would there be any offsets in the form of lower costs?

I think that there would be possibly modest cost. We'd have to kind of look at it in the context of the entire portfolio --

Okay.

The total requirements of our system. Because -- we look at those -- when we look at Hoku and everybody else, we plan as if -- we look at it from a system perspective. Depending on -- LaMont talked about some of the new loads that are coming on already, and so as those loads come on, and if that load doesn't either come on or accelerate, we have to balance all of that as we look forward in the planning process. So, the actual -- identifying that cost is somewhat difficult.

Okay. And then lastly on Hoku, it looks like the commission on April 23rd approved a notice of termination for service. Can you comment on kind of what the status of that is?

Yes. I think that they actually -- they received the notice because they were -- they hadn't paid and they have then subsequently paid.

Oh, okay. Great. Thanks a lot.

Okay.

(Operator Instructions). And that concludes the question and answer session for today. Mr. Keen, I will turn the conference back to you.

Actually, this is Darrel, and I just want to remind everyone that, first of all, our annual shareholder meeting is coming up on May 17, and we will be webcasting that live. We thank you all for participating in our call today, and have a great day.

Thank you.

And that concludes today's conference. Thank you for your participation.