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IDACORP, Inc. (NYSE:IDA)

Q2 2009 Earnings Call

August 6, 2009 4:30 pm ET

Executives

Lawrence Spencer - Director, IR

LaMont Keen - President, CEO

Darrel Anderson - SVP Administrative Services, CFO

Ric Gale - VP, Regulatory Affairs

Vern Porter - Idaho Power General Manager of Power Production

Analysts

Paul Ridzon - KeyBanc

Brian Russo - Landenburg Thalmann

Emily Christy - RBC Capital Markets

Operator

Welcome to the IDACORP Second Quarter 2009 Conference Call. Today’s call is being recorded and is being webcast live. A complete replay will also be available from the end of the day for a period of 12 months to the company’s website at www.idacorp.com. (Operator Instructions). At this time, I would like to turn the call over to the Director of Investor Relations, Mr. Lawrence Spencer. Please go ahead, sir.

Lawrence Spencer

Welcome to our August 6, second quarter 2009 earnings release conference call. We issued our earnings release before the markets opened today and that document is now posted to our IDACORP website at www.idacorpinc.com. We also filed the Form 10-Q with the SEC this morning and that document is also posted to our IDACORP site.

On the call today we have: LaMont Keen, IDACORP and Idaho Power President and CEO; and Darrel Anderson, IDACORP and Idaho Power Senior Vice President of Administrative Services and CFO. We also have other officers available to help answer questions during the Q&A period.

Before turning the presentation over to LaMont, I’ll cover a few details with you. First our presentation today may contain forward-looking statements, and it is important to note that the Corporation’s future results could differ materially from those discussed. A full discussion of the factors that could cause future results to differ materially can be found in our filings with the Securities and Exchange Commission.

Now I’ll briefly discuss the financial results from today’s earnings press release. Second quarter 2009 net income attributable to IDACORP was $27.5 million, $10 million more than last year’s second quarter. Year-to-date net income attributable to IDACORP was $46.4 million, $7.1 million more than the first six months of 2008.

Idaho Power’s second quarter 2009 net income was $26.3 million compared to $17.7 million in 2008, while Idaho Power’s year-to-date 2009 net income was $45.6 million, which is was $6.6 million greater than the same period in 2008. IDACORP’s earnings increased by $0.19 per diluted share quarter-over-quarter to $0.58 per diluted share and by $0.12 per diluted share on a year-to-date basis to $0.99 per diluted share.

With that I’ll turn the presentation over to LaMont.

J. LaMont Keen

We thank you for your interest in IDACORP. I’m pleased with the improved earnings results Larry just reported. In last quarter’s conference call, I discussed multiple regulatory actions aimed at more accurately reflecting and recovering our cost. These regulatory actions along with better hydroelectric operating conditions helped to contribute to our success in the second quarter.

Idaho Power continues to be active on regulatory matters. In addition to the impact from changes in the PCA mechanism, and the 2008 Idaho general rate increases that became effective in the first quarter, multiple regulatory filings were completed during the second quarter and went into effect on June 1. These items include, the power cost adjustment mechanisms in both Idaho and Oregon. The fixed cost adjustment, which resulted in a small increase in earnings, and increase in our Energy Efficiency Rider to 4.75% and the inclusion of automated metering infrastructure related investments in base rates.

Additionally, on July 31, Idaho Power filed a generate case with the Oregon public utility commission. The filing requested an increase to Oregon revenue of approximately $7.3 million or 22.6%. The OPUC can take up to 10 months to review the company’s request. A heavy reliance on low cost hydroelectric generation also contributed to our improved earnings. Hydroelectric generation for the second quarter of 2009 was substantially better than the same period in 2008.

Above normal, June rainfall and near normal run-off from an improved snow pack resulted in 2009 second quarter hydro generation 43% above 2008 second quarter production. As of July 31, reservoir levels in selective Federal reservoirs upstream at Brownlee were at a 122% of average for that time of year. Observed stream flows in Brownlee during this year’s April through July period were 5.6 million acre feet or 89% of the average an increase over the actual 2008 April through July inflow of 4.4 million acre feet.

The cooler weather and greater precipitation did reduce residential and irrigation sales however, impacting overall financial results. Changing tracks a little bit, since we last recorded a number of events that occurred that continued to build upon our growth strategies. I will now briefly comment on a few of them

In April, the Idaho Ratemaking Treatment Act was signed into law and became effective in Idaho on July 1. This legislation establishes a process whereby the IPUC may authorize and pre-approve ratemaking treatment for qualified capital construction projects. If utilized by the IPUC, the legislation can provide additional surety to capital markets, the large utility investments are prudent and pose less risk of financial loss.

The Langley Gulch power plant Certificate of Public Convenience and Necessity or CPCN hearing before the Idaho Public Utilities Commission occurred in July, where Idaho Power is requesting authorization to construct, own, and operate the power plant and include the project in Idaho Powers base rates.

A number of interveners contested issuing the CPCN in the company’s desired timeframe. However, Idaho Power’s request is well supported by testimony of company witnesses and comments from many organizations, including area Mayors, the Boise Valley Metro Chamber of Commerce, local Trade Unions and other parties. An order is expected in the third quarter. If the IPUC issues the CPCN in a form that permits Idaho Power to secure financing on acceptable terms, the company expects to spend between 50 and 55 million during 2009 on this project.

In response to an Act, one of the American Recovery and Reinvestment Act of 2009, Idaho Power continues to evaluate opportunities under the Act as the details are clarified. On July 15, Idaho Power submitted the Letter of Intent with the Department of Energy regarding the company’s non-binding attempt, intension to apply for one of DoEs integrated and/or cross-cutting systems brands.

The brand application to the DoE was submitted today and it details the $45 million of currently budgeted project funds, Idaho Power expects to invest in Smart Grid technology, as well as incremental projects that would be funded if we’re awarded a DoE matching grant. We are currently on schedule and budget with our AMI efforts and believe this grant would enhance our efforts in Smart Grid development.

The company received good news in the 2009 Electric Utility Residential Customer Satisfaction Study results released in July by JD Power and Associates. Idaho Power saw improvements in nearly every category of the study. The company rank in the top 20% in the overall customer satisfaction index and was the highest ranked Investor-owned utility in the West region mid-sized segment.

Additionally, Idaho Power scored highest of all 121 utilities in the study with regard to the amount of information provided to customers during outages. I congratulate our employees for attaining high customer satisfaction marks in a challenging economic climate, while advancing claims for infrastructure investments and project site selection, pursuing an active regulatory strategy, and delivering improving returns to our owners.

Looking ahead, we continue to press forward on plans to expand our generation and transmission capacity to meet our customers future energy needs. We are fully cognizant of the current economic times and still some what unsettled capital markets and will not proceed without full regulatory support. Working within that constraint, we believe it is vital to the future economic vitality of our service area and such steps are taken today.

At the same time, we continue to actively manage all of our operating costs and capital expenditures to limit near-term cost impacts on our customers and to enhance returns for our owners. I’ll now turn it over to Darrel Anderson, who will update you on our financial results.

Darrel Anderson

Today, I will discuss some of the key second quarter 2009 earnings drivers. Our current liquidity positions at Idaho Power and IDACORP along with financing activities. And then provide an update to the 2009 key operating and financial metrics. After that, we look forward to taking your questions.

As LaMont shared in the earnings release, the reported results demonstrate our continued progress toward achieving our loud return on average equity. Of the 12 months ended June 30, 2009, we earned a return on average equity of 8.3%, compared to 7.9% and 7.1% for calendar years 2008 and 2007, respectively. The results represent the combined contributions of our ongoing regulatory strategy, cost containment efforts, and improved operating condition offset by impacts of weather and economic slowdown.

Included in our earnings release and Form 10-Q is a summary of key items impacting comparability of earnings between periods. Idaho Power accounted for 8.6 million of the $10 million increase in net income, as compared to second quarter 2008. The improved financial results were a combination of positive changes to our PCA regulatory mechanisms in Idaho and Oregon and improved operating conditions partially offset by a reduction in energy sales.

In May 2009, the Oregon Public Utility Commission issued a stipulation allowing the deferral of $6.4 million in excess power supply costs incurred prior 2009, which increased earnings in the quarter. In addition, in May 2008, Idaho Public Utility Commission order required a change to the method of reducing - recording base power supply costs retroactive to March 1, 2008.

As a result, the power cost adjustment deferral for the second quarter of 2008 was approximately $6.5 million lower thereby reducing quarterly earning in 2008 as compared to 2009. Both amounts noted above are before any income tax effects.

Continued impacts from the May 2008, Idaho Public Utility Commission order is expected to reduce third quarter 2009 net income by approximately $4.2 million as compared to the third quarter 2008. We included a table summarizing these changes in our Form 10-Q.

While the distribution methodology use does not affect the total amount of net base power supply cost, we use to calculate PCA deferral for a full year, it does affect the quarters in which they are allocated and thus impacts quarterly results. Given that we haven’t agreed upon methodology in place now comparability issues should be minimized after this year.

General business revenues increased $9.5 million for the quarter and $30.1 million year-to-date, as compared to the same periods in 2008. The increase is mostly attributable to a series of changes in retail base rates in 2008 and 2009 combined with PCA rate increases in June 2008 and 2009.

These rate changes accounted for increase in revenues of $23.9 million for the quarter and $52.2 million year-to-date. These increases were partially offset by decreases of $17.4 million for the quarter and $27.1 million year-to-date due to milder temperatures, increased precipitation and a weaker economy.

Total energy sales were down 8% and 6% for the three-month and six-month periods respectively. For the second quarter and first six months of 2009 irrigation sales were down 19% while industrial sales were down 9% for the quarter and 6% year-to-date compared to 2008.

Declines in sales volume are partially mitigated by the low growth adjustment rate and the fixed cost adjustment decoupling mechanism. Hydroelectric generation in the second quarter of 2009 was 43% greater than last year’s second quarter. This resulted in the net power supply cost falling by $30.4 million or approximately 55%. Net power supply costs are defined as fuel, purchase power, and third party transmission expenses less off system sales.

Hydroelectric generation for the first half of 2009 was 22% higher in the comparable period in 2008 resulting in $35.7 million or approximately 34% lower net power supply costs. Other operation and maintenance expenses increased $900,000 or 1.3% for the quarter and $1.3 million or less than 1% year-to-date. Increases for the quarter were primarily attributable to $3.4 million increases in payroll-related expenses, and an $800,000 increase in charges for uncollectible account partially offset by $3.2 million decrease in outside in response to ongoing cost containment measures.

The year-to-date increase in operation maintenance expenses is attributable to $5.5 million increase in payroll-related expenses, a $1.7 million increase in FERC fees refunded to customers, a $1 million increase in charges for uncollectible account, and $1.2 million increase in thermal operation maintenance expenses. These increases were partially offset by $4.3 million decrease in the use of outside services and a $3.1 million decrease from the fixed cost adjustment mechanism.

I’ll now discuss IDACORP’s liquidity for the year-to-date 2009. Cash flow from operations improved to $110.6 million from $53.5 million. The increase is primarily the result of a $44 million improvement in the collection of previously deferred power supply costs and $13 million from federal income tax refund. These improvements were partially offset by the refund of $13 million to transmission customers after receiving a final order from the Federal Energy Regulatory Commission on Idaho Power’s open access transmission tariffs.

Cash used for investing activities decreased by $19.6 million in the first six months 2009, compared to the same period in 2008. Idaho Power’s expenditures for utility plant were $25.1 million left in 2008 reflecting the reduction in new customer connection and capital expenditure management.

The outflows were partially offset by $8.2 million received from the sale of bond investments at IDACORP Financial, and $2.3 million in proceeds from the sale of emission allowances by Idaho Power.

Key financing activities during the first six months of the year included the issuance of a $100 of Idaho Power tenure first mortgage bonds with a coupon of 6.15%. Net repayment of $72 million in short-term debt, and proceeds of $4.9 million in new equity issued under the dividend reinvestment plan and employee benefit plans.

Commercial paper outstanding at June 30, 2009 was $42.4 million at IDACORP and $32.8 million at Idaho Power. Current revolving credit facilities at IDACORP and Idaho Power are $100 million and $300 million, respectively. With $57.6 million available at IDACORP, and $242.9 million available at Idaho Power at June 30, 2009; both of these facilities expire in April of 2012.

I’ll now update you on the key operating and financial metrics for 2009. These are also shown in both the earnings release issued earlier today, and our second quarter Form 10-Q. Our expected range of capital expenditures at Idaho Power Company remains unchanged for 2009.

As LaMont mentioned if the Idaho Commission issues the CPCN on the Langley Gulch power plant on acceptable terms, the company to spend between 50 and $55 million on that project raising the capital range from $220 million to $230 million to $270 million to $285 million. We reduced our estimated capital expenditures for the 2010, 2011 timeframes by approximately $50 million to between $500 million and $540 million excluding the Langley Gulch power plant.

The reduction represents our continued emphasis on only critical infrastructure needs relating to system reliability and resource adequacy. We continue to finance the capital program with a combination of internally generated funds, equity and debt. We actively manage our consolidated equity capital position based upon capital availability, regulatory requirements and raving agency considerations.

Based on current operating cash flow assumptions and our reduced capital expenditures requirements for 2010, we expect 2009 and 2010 internal cash generation will be sufficient to provide the majority of our remaining capital requirements, including estimates for the Langley Gulch power plant. While we expect little, if any need to access the equity capital market outside of our dividend reinvestment program and employee-related plan, should we need or want to access the equity capital markets; we have access to our continuous equity program with approximately 2.6 million shares of common stock available.

As of June 30, our capital structure including notes payable and the current portion of long-term debt was 48% debt and 52% equity at IDACORP and 54% debt and 46% at Idaho Power company. We narrowed the range of estimated hydroelectric generation to between 7.5 million and 8.5 million megawatt hours, based on actual generation through June and estimated ranges of generation for the balance of the year.

Key to the change in the range is above normal perception during June and the impacts of above normal stories level in reservoirs above Brownlee dam. We reduced the range of our estimated effective income tax rates due to the reduction of the 2009 federal bonus depreciation provisions by the State of Idaho and the settlement of the 2006 internal revenue service examination. Idaho’s adoption of the federal bonus depreciation provision created a related flow-through benefit, thereby reducing the effective tax rate at Idaho Power Company.

This concludes my financial update. Now we would like to respond to your questions.

Question-and-Answers Session

Operator

Thank you. Ladies and gentlemen, we will now begin the question-and-answer session. (Operator Instructions). Your first question comes from Paul Ridzon of KeyBanc. Please proceed.

Paul Ridzon - KeyBanc

Darrel, did you say that 6.4 million from Oregon was pre-tax or after-tax?

Darrel Anderson

The 6.4 million from Oregon as we reported is a pre-tax number and go ahead, Paul, go ahead.

Paul Ridzon - KeyBanc

I was just looking at the reconciliation on the second page of your release?

Darrel Anderson

All right.

Paul Ridzon - KeyBanc

That totals to the change in net income right?

Darrel Anderson

That’s correct. The changes with respect to the difference in the tax rate on the gross basis is basically net of income from the other line.

Operator

Your next question comes from the line of Brian Russo of Landenburg Thalmann. Please proceed.

Brian Russo - Landenburg Thalmann

Earlier you mentioned your actual ROEs could you just repeat that please?

Unidentified Company Speaker

Starting with respect to 12 months ended June 30, 8.3% and then 7.9% for the calendar 2008 and 7.1% for the calendar year 2007.

Brian Russo - Landenburg Thalmann

Obviously, the ROE is improving with rate release and so forth. So I guess, that you continue to trend up on a 12 month rolling basis through you know the end of the year.

Unidentified Company Speaker

Our goal is that that number it would be trending up obviously as we continue to look our regulatory strategies, we’ll continue to look to close those gaps.

Brian Russo - Landenburg Thalmann

When can we expect you to file your next Idaho rate case?

Unidentified Company Speaker

First of all, Brian, one of the things we are doing is, actually finishing up the Langley proceeding. What we are also doing, we just filed the Oregon proceed and so we are in the process of accepting where we are with Idaho. If you know our history, we’ve historically kind of had these cases go into effect in June, and if that works to be the same path the first thing you would see from us is, sometime I know it’s been tend towards the end of this month if that was going to be our plan. We are continuing assess that, as we just finished up getting Oregon case filed.

Brian Russo - Landenburg Thalmann

In the event that you don’t file for 2010 rate release in Idaho, can you still earn your ROE or would there be some regulatory lag?

Unidentified Company Speaker

Given obviously where our account results are, we’d continue to have regulatory lag both in the operating expense side and we were still making significant investment. We need to continue to stay on that and stay as current as we can and that is really, that is our goal.

Brian Russo - Landenburg Thalmann

When I look at your O&M expense year-to-date, about 143.4 million, if you annualize that that’s 286, that kind of falls in kind of the high-end of your O&M guidance range. I am wondering if there are other things left on the plate that you guys can kind a do in the second half of 2009 to bring that maybe down to lower-end?

Unidentified Company Speaker

We are continuing to focus on all aspect of the operating expense side of things and one of things we did do or continue to do is look at our labor cost obviously that’s in line into it - that you will see an increase then, but that’s part of that because cost have moved out of the capital side in the O&M side, as capital items have moved around. We continue to look at that. We are looking all aspects of the business and we will continue to do so. The reason we haven’t modified the range that we still think we’re going to be in and around that range as we see here today.

Brian Russo - Landenburg Thalmann

Lastly, what type of load growth due you expect for the full year ‘09?

Unidentified Company Speaker

For 2009, it’s based on what you’ve seen through the year-to-date at least you’ve seen the declined, but our estimates are into the 1.5 to 2% kind of numbers longer term, but for balance of the year we continue to see some impacts not only from our energy efficiency programs, but as well as from some of the economic factors and also you’ve seen weather issues that you saw here in the second quarter.

Operator

(Operator Instructions). Your next question comes from the line of Emily Christy of RBC Capital Markets. Please proceed.

Emily Christy - RBC Capital Markets

In terms of the Oregon rate case, I know, (your question) ROE of 11.25%, have you broken out what your earnings for ROE in just the Oregon territory at this point?

Darrel Anderson

Emily, I’m looking here at Ric Gale, here right now, to see if we. We are underearning in Oregon that’s by first good starting plan, and has been for a while. As you know, we haven’t filed in Oregon for five years. Obviously, the reason we see the increase (delayed assets), because it’s been a five year lag and (some I believe) since filed. So we have been underearning there for quite sometime; and Ric, I don’t know if you want to comment on that?

Ric Gale

All I can do is underscore what Darrel said, we’ve been battling resolution of our power supply costs in there since the last June. Cut that result and that’s why we’re back for a significant increase to base.

Emily Christy - RBC Capital Markets

In terms of Langley Gulch, I know, you had hearing in July, could you give us some colors to how those hearings went?

Unidentified Company Speaker

Yes. Emily, we are going to have Vern Porter going to speak to how those, Vern, who leads our Langley Gulch process and hence he is one of the folks who testified and who was on the stand. We’ll have, Vern, can give you an update on how those proceedings went.

Vern Porter

The company put on a strong case with respect to the need and for the project and for the fairness of the proceeds and things went fairly well. Now of course, we are waiting for the Commission to respond to make a decision and we expect that decision to be forthcoming here in the third quarter. As far as, we’re kind of in a waiting game there. As far as the process has gone with respect to other assets of Langley Gulch, things are going very well. We had some open-houses and had a very favorable response from the public regarding the project. People like the location. We’ve had approvals from the Payette County on our comprehensive changes, plan change, and we’re having another open-house tonight. Things are going forward very well with respect to permitting side of things and project moving forward quite nicely.

Emily Christy - RBC Capital Markets

Okay.

J. LaMont Keen

This is LaMont too. I will give you couple, I’ll chunk it up a little comments from my area, and that the company believes that the resources we have today are needed to serve the loads of the customers we have today and for us to be prepared to support the economy of Southern Idaho on our service territory in the future we need new generating resources and ultimately new transmission interconnections, in order to be able to be a good partner for the State of Idaho in the development of growing economy here.

There are folks that intervened in the case, who believe that as a result of the current downturn and the fact that with the loss of some industrial low this year, our loads will be fairly flat for 2009, and that negates the need for an additional resource or resource from that timeframe. We don’t agree with that as we said in my comments and most of the business leaders and civic leaders in the area support in the need for us to have additional base load generating capacity, so that’s our case and that’s our story.

It’s really in the Commission’s hands and we’re looking to them to give us an order not only says go, but it says go in a way that gives us support that when we built the plant we’re going to be able to recover those cost. That’s the situation today. We’re prepared to proceed if we get that dream light, and if not, then we’re going to have to reconsider.

Emily Christy - RBC Capital Markets

Just one more, what are next milestones we can expect for the two major transmission projects that are in expiration stage right now?

Unidentified Company Speaker

This is (Chip Sait) I’m the Manager of Transmission Policy and Development. The two transmission projects we’re referring to are Gateway West project, in the Boardman to Hemingway 500kb project. Those projects are in public hearings in permitting cases at this point in time.

We have a customer advisory process going on, on the Boardman to Hemingway project, looking at potential routing that is expected to run thorough the remainder of this fall. Likewise, we have a brief pause in the (need of) permitting process factored the VLM on the Gateway West project looking at additional routes and those are to be submitted by September 4 or 14, I can’t remember, which date that is, but they are coming up fairly quickly. I think, it supports and to allow the need for process to continue on with the draft Environmental Impact Statement coming up probably next spring.

Emily Christy - RBC Capital Markets

Okay. Thank you very much.

J. LaMont Keen

This is LaMont again. Chunking now went up a little bit I think we can say we’re continuing to diligently purse those projects however we’re certainly aware that its difficult to site anything kind of in United States and even our service territory today specially 100s of miles of transmission line. While we’re going after those diligently and ultimately think we’ll prevail, it’s going to be a stop and go process for a while as we work through the various agencies and other things in order to obtain those approvals. We’ll keep you informed, but it’s really not a process, we can control other than in our efforts to achieve it.

Operator

That concludes the question-and-answer session for today. We have no further questions in the queue. Mr. Keen, I will turn the call back to you.

J. LaMont Keen

We appreciate all of your attention today and your interest in IDACORP. We do look forward to providing you further updates at the end of the third quarter and we will probably be seeing many of you at the EEI Financial Conference in November. Thanks again for your interest, and have a good day. Good bye.

Operator: That concludes today’s conference. Thank you for your participation.

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