HomeMy WebLinkAboutCOC rbc-8-8-08.doc06:17am EDT 8-Aug-08 RBC Capital Markets (US) (Lasan Johong) IDA IDA.N
RBC: IDA: Quarter miss reflects timing issues and weather Part 1
RBC CAPITAL MARKETS EQUITY RESEARCH
Price Target Revision | COMMENT
August 8, 2008
IDACORP, Inc.
NYSE:IDA
Sector Perform
Above Average Risk
Quarter miss reflects timing issues and weather
Priced as of prior trading day's market close, EST (unless otherwise stated).
For required disclosures, please see Required Disclosures section at the end
of this comment.
RBC Capital Markets Corp.
Lasan Johong (Analyst)
(212) 428-6462; lasan.johong@rbccm.com
Emily Christy (Associate)
(212) 428-6970; emily.christy@rbccm.com
Ella Faynzilberg (Associate)
(212) 428-6492; ella.faynzilberg@rbccm.com
Price: 29.66 Price Target: 35.00(prev:38.00)
Shares O/S (MM): 44.1 Implied All-In Return: 22%
Dividend: 1.20 Market Cap (MM): 1,308
Yield: 4.0%
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All values in USD unless otherwise noted.
FY Dec 2007A 2008E 2009E
Adj EPS - FD 1.86 1.80 2.14
Prev. 2.01
P/AEPS 15.9x 16.5x 13.9x
Adj CFPS - FD 1.77 4.55 4.96
Prev. 4.84 5.08
P/ACFPS 16.8x 6.5x 6.0x
EBITDA/Share - FD 5.92 6.46 8.08
Prev. 6.97 8.36
FCFPS - FD (2.63) (1.08) (0.76)
Prev. (1.12) (0.51)
P/FCF NM NM NM
Adj EPS - FD Q1 Q2 Q3 Q4
2007 0.56A 0.42A 0.65A 0.23A
2008 0.48A 0.35A 0.71E 0.26E
Prev. 0.51E 0.31E
Adj CFPS - FD
2007 0.98A 0.30A 0.50A 0.00A
2008 1.02A 1.08A 1.45E 1.01E
Prev. 1.27E 1.47E 1.08E
EBITDA/Share - FD
2007 1.60A 1.41A 1.71A 1.21A
2008 1.57A 1.46A 2.00E 1.43E
Prev. 1.78E 2.06E 1.56E
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IDA reported 2Q08 adjusted-EPS of $0.35 vs. consensus of $0.42 and our $0.51
estimate
Maintaining CNAV of $38 and SP rating. Lowering Target Price to $35 from $38
to reflect recent market weakness.
Rate increase offsets lower demand at the utility
The implementation of higher retail rates and higher power cost adjustment
rates, which took respective effect in March and June 2008, increased year-
over-year revenues by $19MM. Usage by irrigation customers, however, was 16%
lower than 2Q07 due to weather. Customer growth continued, but at a slightly
slower rate of 1.8% compared to 2.0% in 1Q08.
Hydrology a relative bright spot compared to recent history
Although actual April to July reservoir inflows were still only 70% of the
30yr average at 4.4 million acre-feet (maf), weather and climate conditions
have been favorable year-over-year. Hydroelectric generation for the quarter,
at 2,077MWh was up year-over-year by 35%, Brownlee Reservoir storage was 113%
of average in July, and IDA may add at least 69,000 maf to peak summer flows
via water leases. Accordingly, IDA has increased the lower end and refined the
range of its expectations for hydro generation to 6.5-7.5MM MWh from 6.0-8.0MM
MWh.
Regulatory Environment at a Crossroads
IDA is working to mitigate the regulatory risk that has plagued the company.
Since 1Q08, IDA filed a general rate case requesting a $67MM revenue increase,
held its first regulatory workshop to discuss the PCA and LGAR mechanisms, and
filed an application for its proposed $71MM AMI deployment. IDA hopes to build
on its recent success in OR, where the reign of free power finally ended in
June with the approved PCAM rates. As proceedings begin, we expect to conduct
a more thorough analysis of the proposed changes and possible outcomes.
Conclusion: Little has changed for IDA in the longer-term, but potential
catalysts are on the horizon
Hydrology conditions remain as the backbone of IDA's success or failure under
the existing regulatory framework, but regulatory acknowledgement of this risk
and resulting pressure on the company's financial health seems to be taking
hold. Formal discussions are certainly a step in the right direction, but of
course only positive results can tip the scale away from risk and towards
reward.
Details
Growing power gap remains a question, magnified by regulatory shortcomings
As customer and demand growth continue, IDA's reliance on purchased power
will increase. With current flaws in the PCA and LGAR mechanisms, this growth
could actually impair earnings. Construction and ownership of a new base load
power plant could turn this pressure on earnings into an accretive benefit.
Since scrapping preliminary plans for an IGCC plant (fortunately, in our
opinion), IDA has yet to announce a replacement project or alternative plan
to fill the expected power gap. We look for more clarity on this issue when
IDA files its updated Integrated Resource Plan in 2009.
Regulatory Updates:
IDA filed its General Rate Case to the IPUC
The company filed for a $67MM annual increase in revenues, an 11.25% ROE and
an equity ratio of approximately 50%. As the last rate case was settled
without singling out these metrics, relevant comparisons to existing rates
are somewhat murky. For the prior rate case, IDA received roughly half of its
requested $64MM revenue increase in its rate case, but uncertainty lingered
as to which costs were covered by the settlement, which costs were
disallowed, and which costs remain pending for the next rate case. Through
this rate case, IDA seeks to establish a solidified forecast test-year
methodology and an applicable ROE for a specific equity ratio. This filing
will base costs on forecasts for 2008 that are built from the last audited
year, 2007. As the forecasting methodology will be new to the commission,
this hearing may take some time. It is our hope that the details be examined
and the issues fully resolved, rather than reaching another cash settlement
agreement filled with loose-ends. If the timing of costs and projects can be
more favorably treated by this process, shareholder value would increase
accordingly.
Danskin added to rate base
The 166MW gas-fired Danskin peaking plant began commercial operations in
March, 2008. Effective as of June 1, 2008, $64.2MM was added to rate base for
this plant. The associated annual revenue increases are approximately $8.9MM.
PCA amount approved, allocation methodology changed
In May, the IPUC approved $73.3MM in purchased power cost recovery.
Additionally, the IPUC determined that cost recovery would be allocated
evenly on a monthly basis, rather than seasonally with MWh usage. The change
in distribution should not have an impact on longer term annual results, but
quarterly fluctuations are expected to diminish.
Certificate of Public Convenience and Necessity filed for AMI deployment
proposal
Under the deployment plan, IDA will install the new meters to nearly all of
its customers, beginning in 2008 and ending in 2011. Although IDA has begun
to contract for supplies and materials related to this initiative, it has
retained the option to cancel all obligations if regulatory approvals are not
in line with forecasts. If approved, IDA's AMI plan will have a $12.2MM
positive impact on 2009 earnings. We have not yet included this upside in our
current model and will wait for the regulatory process to conclude.
Regulatory progress in OR: Power Cost Adjustment Mechanism (PCAM) approved
Cost recovery from the PCAM in OR took effect in June 2008. In May the OPUC
approved IDA's updated forecast of its expected purchased power costs for
April 2008 through March 2009 in the amount of $4.8MM. Prior to the PCAM, in
the last OR general rate case regulators imposed a negative value to
purchased power expenses, assuming that the owned generation would be not
only sufficient to serve the load, but also enough for off-system sales.
VALUATION
Our calculated net-asset-value (CNAV) is $38 and our Target Price is $35. We
determine our CNAV based on a full discounted cash flow model using an
average of Free Cash Flow to the Firm and Free Cash Flow to Equity. We apply
a multistage growth rate with a terminal multiple of 11.0x based on a dynamic
WACC with an initial rate of 8.10%. The terminal value is calculated
approximately 25 years forward.
Our target price is set at a discount to our CNAV due to recent market
weakness and economic uncertainty in the near term. As a pure-play electric
utility with a significant hydroelectric generation fleet, IDA operates in a
heavily regulated environment. Considering the risk management policies of
IDA, the Idaho regulatory structure, solid operations and the above-average
population growth for the service territory, the company continues to perform
as expected.
PRICE TARGET IMPEDIMENT
Volatile hydrology, unfavorable regulatory decisions, poor growth project
selections, operational setbacks, changes in credit ratings, environmental
regulations, cost overruns with the capex projects and weather.
COMPANY DESCRIPTION
IDACORP is a holding company for the following subsidiaries: Idaho Power
Company, IDACORP Financial, and Ida-West Energy. Idaho Power Company (IPC) is
a regulated utility serving approximately 472,000 customers in Idaho and
western Oregon. Through its regulated operations, IPC generates, purchases,
transmits, distributes, and sells electric power. Through its 17
hydroelectric power plants, IPC is one of few utilities with a predominant
hydro generating base. The company also owns and operates coal and natural
gas-fired plants to round out its approximately 3,300MW power portfolio.
Additionally, IPC has 4,600 miles of transmission lines and 26,000 miles of
distribution lines. IDACORP Financial is an investment company with a focus
on affordable housing and historic preservation projects. Ida-West Energy is
an independent power project development company with 44.6MW of combined
interest in nine hydroelectric power plants in California and Idaho.
REQUIRED DISCLOSURES
EXPLANATION OF RBC CAPITAL MARKETS RATING SYSTEM
An analyst's 'sector' is the universe of companies for which the analyst
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the next 12 months relative to the analyst's sector average.
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expected to significantly outperform the sector over 12 months; provides best
risk-reward ratio; approximately 10% of analyst's recommendations.
Outperform (O): Expected to materially outperform sector average over 12
months.
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months.
Underperform (U): Returns expected to be materially below sector average over
12 months.
Risk Qualifiers (any of the following criteria may be present):
Average Risk (Avg): Volatility and risk expected to be comparable to sector;
average revenue and earnings predictability; no significant cash flow/financing
concerns over coming 12-24 months; fairly liquid.
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average revenue and earnings predictability; may not be suitable for a
significant class of individual equity investors; may have negative cash flow;
low market cap or float.
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potential balance sheet concerns; risk of being delisted.
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Distribution of Ratings, Firmwide
RBC Capital Markets
Investment
Banking
Serv./Past 12
Mos.
Rating Count Percent Count Percent
BUY(TP/O) 551 48.12 190 34.48
HOLD(SP) 512 44.72 120 23.44
SELL(U) 82 7.16 16 19.51
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A member company of RBC Capital Markets or one of its affiliates received
compensation for products or services other than investment banking services
from IDACORP, Inc. during the past 12 months. During this time, a member
company of RBC Capital Markets or one of its affiliates provided non-securities
services to IDACORP, Inc.
RBC Capital Markets is currently providing IDACORP, Inc. with non-securities
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RBC Capital Markets has provided IDACORP, Inc. with non-securities services in
the past 12 months.
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Continued in part 2...
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