HALIFAX, Nov. 7 /CNW/ - (EMA-TSX): Emera Inc.'s consolidated net earnings were $6.5 million in Q3 2008, compared to $40.9 million for the same period in 2007. Earnings per share were $0.05 in the quarter compared to $0.37 in 2007. Two significant accounting adjustments negatively impacted earnings in the quarter. Excluding these accounting adjustments, earnings per share would have been $0.22. Mark-to-market accounting losses in Bear Swamp reduced earnings per share by $0.07 in the quarter. As well, the valuation of a long-term receivable in Nova Scotia Power decreased in the quarter causing a further $0.10 reduction in earnings per share.
Year-to-date earnings were $118.8 million for the first three quarters of 2008 compared to $114.7 million for the same period in 2007. Earnings per share were $1.06 for the nine months ended September 30, 2008, compared to $1.03 for the same period in 2007, inclusive of mark-to-market accounting changes.
Nova Scotia Power's earnings were $2.3 million in Q3 2008, compared to $25 million in Q3 2007. As expected, fuel costs in NSPI increased significantly in the quarter due to higher commodity costs. Two additional factors contributed to the quarter over quarter change in NSPI. The decreased valuation of a long-term receivable reduced earnings by $10.8 million in the quarter. Excluding the effect of the long-term receivable, NSPI's earnings would have been $13.1 million in the quarter. As well, earnings were also higher in 2007 due to a $10.8 million tax recovery in the third quarter last year. NSPI's outlook for the full year 2008 is to earn within its allowed range of rate of return.
"Despite expected weaker financial results in the quarter, we are pleased with our progress so far this year," said Chris Huskilson, President and CEO of Emera. "Brunswick Pipeline construction is nearing completion, we acquired 25% of the Grand Bahama Power Company and NSPI's 2009 rate settlement was approved. In light of this progress in our businesses, the Board of Directors announced a 6% increase in our dividend on October 20th."
Bangor Hydro-Electric contributed $6.5 million to consolidated net earnings in Q3 2008, compared to $9.1 million in Q3 2007. This decrease relates primarily to the capitalization of costs in 2007 related to construction of the Northeast Reliability Interconnect transmission line.
Emera's Other operations had a net loss of $2.3 million in Q3 2008, compared to a contribution of $6.8 million in Q3 2007. This decrease relates to mark-to-market accounting changes in Bear Swamp offset by lower income taxes.
Forward Looking Information
This news release contains forward looking information. Actual future results may differ materially. Additional financial and operational information is filed electronically with various securities commissions in Canada through the System for Electronic Document Analysis and Retrieval (SEDAR).
Teleconference Call
The company will be hosting a teleconference at 4:00 pm Atlantic time today (3:00 pm Toronto/Montreal/New York; 2:00 pm Winnipeg; 12:00 pm Vancouver) to discuss the Q3 2008 financial results.
Analysts and other interested parties wanting to participate in the call should dial 1-888-575-8232 (in Toronto 416-406-6419) at least 10 minutes prior to the start of the call. No pass code is required. The teleconference will be recorded. If you are unable to join the teleconference live, you can dial for playback toll-free at 1-800-408-3053 (in Toronto 416-695-5800), access code 3271434(number sign) (available until midnight, Friday, November 21, 2008). The teleconference will also be webcast live at www.emera.com and available for playback for one year.
About Emera
Emera Inc. (EMA-TSX) is an energy and services company with $4.8 billion in assets. Electricity is Emera's core business. The company has two wholly-owned regulated electric utility subsidiaries, Nova Scotia Power Inc. and Bangor Hydro-Electric Company, which together serve 600,000 customers. Emera also owns 19% of St. Lucia Electricity Services Limited, which serves more than 50,000 customers on the Caribbean island of St. Lucia. In addition to its electric utility investments, Emera has a joint venture interest in Bear Swamp, a 600 megawatt pumped storage hydro-electric facility in northern Massachusetts; a 12.9% interest in the Maritimes & Northeast Pipeline; a 7.4% interest in Open Hydro and Emera Energy Services which manages energy assets on behalf of third parties. Visit Emera on the web at www.emera.com.
Management's Discussion & Analysis
As at November 7, 2008
Management's Discussion and Analysis ("MD&A") provides a review of the results of operations of Emera Inc. and its primary subsidiaries and investments during the third quarter of 2008 relative to 2007, and its financial position at September 30, 2008 relative to December 31, 2007. Certain factors that may affect future operations are also discussed. Such comments will be affected by, and may involve, known and unknown risks and uncertainties that may cause the actual results of the company to be materially different from those expressed or implied. Those risks and uncertainties include, but are not limited to, weather, commodity prices including supplier fulfillment of contractual agreements and obligations, interest rates, foreign exchange, regulatory requirements and general economic conditions. To enhance shareholders' understanding, certain multi-year historical financial and statistical information is presented.
This discussion and analysis should be read in conjunction with the Emera Inc. unaudited consolidated financial statements and supporting notes as at and for the nine month period ended September 30, 2008 and the Emera Inc. MD&A and annual audited consolidated financial statements and supporting notes as at and for the year ended December 31, 2007. Emera follows Canadian Generally Accepted Accounting Principles ("GAAP"). Emera's wholly-owned subsidiary, Nova Scotia Power Inc.'s accounting policies are subject to examination and approval by the Nova Scotia Utility and Review Board. Emera's wholly-owned subsidiary, Bangor Hydro-Electric Company's accounting policies are subject to examination and approval by the Maine Public Utilities Commission and the Federal Energy Regulatory Commission. The rate-regulated accounting policies of Nova Scotia Power and Bangor Hydro may differ from GAAP for non rate-regulated companies.
Throughout this discussion, "Emera Inc." and "Emera" refer to Emera Inc. and all of its consolidated subsidiaries and affiliates.
All amounts are in Canadian dollars ("CAD") except for the Bangor Hydro section of the MD&A, which is reported in US dollars ("USD") unless otherwise stated.
Additional information related to Emera, including the company's Annual Information Form, can be found on SEDAR at www.sedar.com.
Introduction and Strategic Overview
Emera is a Canadian energy holding company headquartered in Halifax, Nova Scotia. The company invests in electricity generation, transmission and distribution as well as gas transportation and energy marketing.
Most of Emera's revenues are earned by its two regulated electric utilities which it owns and operates in Northeastern North America. Nova Scotia Power Inc. ("NSPI") is an electricity generation, transmission and distribution company with $3.2 billion of assets providing service to 480,000 customers in the province of Nova Scotia, and Bangor Hydro-Electric Company ("BHE") is an electricity transmission and distribution company with $665 million of assets serving 117,000 customers in eastern Maine. Both businesses operate as monopolies in their service territories, and together comprise approximately 90% of Emera's consolidated revenues. The success of Emera's electric utilities is integral to the creation of shareholder value, providing substantial earnings and cash flow to fund dividends and reinvestment. The essential nature of the services provided, the monopoly positions, and the regulated market structures means that NSPI and BHE can generally be expected to produce stable earnings streams within regulated ranges. Nova Scotia and Maine are mature electricity markets, with annual demand growth of approximately 1%. Accordingly, Emera looks beyond its existing regulated electricity business to supplement organic growth.
Emera's goal is to deliver annual consolidated earnings growth of 4% - 6%, and build and diversify its earnings base. To accomplish this, Emera will continue to seek growth from its existing businesses and will leverage its core strength in the electricity business as it pursues both acquisitions and greenfield development opportunities in regulated electricity transmission and distribution and low risk generation. Emera's growth strategy also includes serving the United States' market through transmission development and capitalizing on opportunities in related energy infrastructure businesses appropriate to its risk profile, where its development, commercial and operational skills are needed.
Emera is growing its business through the following investments:
- Bear Swamp, a 50/50 joint venture in a 600 megawatt pumped storage
hydro-electric facility in northern Massachusetts.
- Emera Energy Services, a physical energy business which purchases and
sells natural gas and electricity and provides related energy asset
management services.
- Brunswick Pipeline, a 145 kilometer pipeline under construction that
will deliver natural gas from the Canaport(TM) Liquefied Natural Gas
import terminal, also under construction, near Saint John,
New Brunswick, to markets in Canada and the US northeast.
- A 12.9% interest in the $2 billion, 1,400 kilometer Maritimes &
Northeast Pipeline ("M&NP") that transports Nova Scotia's offshore
natural gas to markets in Maritime Canada and the northeastern
United States.
- A 19% interest in St. Lucia Electricity Services ("Lucelec"), a
vertically integrated electric utility on the Caribbean Island of
St. Lucia, which was acquired in January 2007.
- A 7.35% interest in OpenHydro Group Limited ("OpenHydro"), an Irish
renewable tidal energy company, which was acquired in February 2008.
Investment in Grand Bahama Power Company Limited ("GBPC")
In September 2008, Emera purchased 25% of GBPC for $42.0 million USD ($44.9 million CAD) through its acquisition of 50% of the shares of ICD Utilities Limited ("ICDU") of the Bahamas. ICDU owns 50% of the shares of GBPC, which is a vertically integrated utility serving 19,000 customers on Grand Bahama Island.
GBPC has 137 megawatts of installed oil-fired generating capacity. The Grand Bahama Port Authority Limited regulates the utility and has granted GBPC a licensed, regulated and exclusive franchise to produce, transmit, and distribute electricity on the island until 2054. There is a fuel pass through mechanism and flexible tariff adjustment policies to ensure that costs are recovered and a reasonable return is earned.
Emera financed the acquisition with existing credit facilities. GBPC is expected to add $2.5 million USD to $5.0 million USD to Emera's annual consolidated net earnings.
Structure of MD&A
This Management's Discussion and Analysis begins with an overview of consolidated results; then presents information on the company's two primary subsidiaries, NSPI and BHE. All other operations, including Bear Swamp, Emera Energy Services, Maritimes & Northeast Pipeline, Lucelec, Brunswick Pipeline, OpenHydro, GBPC, and corporate activities are grouped and discussed as "Other". Significant changes in the consolidated balance sheets, outstanding share data, liquidity and capital resources, financial and commodity instruments, transactions with related parties, changes in accounting policies, dividends and selected quarterly trend information are presented on a consolidated basis.
EMERA CONSOLIDATED
Q3 Operating Unit Contributions
millions of dollars (except Three months ended Nine months ended
earnings per common share) September 30 September 30
-------------------------------------------------------------------------
2008 2007 2008 2007
-------------------------------------------------------------------------
Nova Scotia Power $2.3 $25.0 $91.2 $75.0
Bangor Hydro-Electric 6.5 9.1 16.5 20.8
Other (2.3) 6.8 11.1 18.9
-------------------------------------------------------------------------
Consolidated net earnings $6.5 $40.9 $118.8 $114.7
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Earnings per common share - basic $0.05 $0.37 $1.06 $1.03
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Earnings per common share -
diluted $0.05 $0.35 $1.04 $1.00
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Review of 2008
Emera Inc.'s consolidated net earnings decreased $34.4 million to $6.5
million in Q3 2008 compared to $40.9 million in Q3 2007. Year-to-date, Emera's
consolidated net earnings increased $4.1 million to $118.8 million in 2008
compared to $114.7 million in 2007. Highlights of the changes are summarized
in the following table:
Three months Nine months
ended ended
millions of dollars September 30 September 30
-------------------------------------------------------------------------
Consolidated net earnings - 2007 $40.9 $114.7
(Decreased) increased net earnings in NSPI
due to increased fuel expense, an
electricity price increase on April 1, 2007
and decreased financing charges (22.7) 16.2
Decreased net earnings in Bangor Hydro due
mainly to the benefits received in 2007 on
the NRI transmission line (2.6) (4.3)
Decreased net earnings in Other due mainly to
an unfavourable price position in Bear Swamp (9.1) (7.8)
-------------------------------------------------------------------------
Consolidated net earnings - 2008 $6.5 $118.8
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Basic earnings per share were $0.05 in Q3 2008 compared to $0.37 in Q3
2007; and $1.06 year-to-date in 2008 compared to $1.03 in 2007.
Significant Items
Bear Swamp
As part of its long-term energy and capacity supply agreement with the
Long Island Power Authority ("LIPA"), Bear Swamp has contracted with its
parents to provide the power necessary to produce the requirements of the LIPA
contract. A contract with Emera's joint venture partner is marked-to-market
through earnings as it does not meet the stringent accounting requirements of
hedge accounting. As at September 30, 2008, the fair value of the net
derivative asset was $9.5 million (December 31, 2007 - $10.5 million), which
is subject to market volatility of power prices, and will reverse over the
life of the agreement as it is realized. The agreement expires in 2021.
The mark-to-market adjustments were as follows:
millions of dollars (except Three months ended Nine months ended
earnings per common share) September 30 September 30
-------------------------------------------------------------------------
2008 2007 2008 2007
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Mark-to-market (loss) gain $(12.4) $1.0 $(2.1) $5.2
-------------------------------------------------------------------------
-------------------------------------------------------------------------
After-tax mark-to-market
(loss) gain $(7.3) $0.6 $(1.2) $3.1
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Earnings per common share - basic $0.05 $0.37 $1.06 $1.03
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Earnings per common share - basic,
absent the after-tax mark-to-
market adjustment $0.12 $0.36 $1.07 $1.00
-------------------------------------------------------------------------
-------------------------------------------------------------------------
NOVA SCOTIA POWER INC.
Overview
NSPI is the primary electricity supplier in Nova Scotia, providing over
95% of electricity generation, transmission and distribution in the province.
Nova Scotia Power is regulated under a cost of service model, with rates set
to recover prudently incurred costs of providing electricity service to
customers, and provides an opportunity to earn a prescribed return on equity.
The company is regulated by the Nova Scotia Utility and Review Board ("UARB").
Appointments
On June 18, 2008 Robert Bennett was appointed President & Chief Executive
Officer of NSPI. Mr. Bennett, who was most recently Executive Vice President,
Revenue and Sustainability, succeeds Ralph Tedesco as part of a planned
leadership transition. Mr. Tedesco, who was Nova Scotia Power's President and
Chief Executive Officer, remains a member of Nova Scotia Power's Board of
Directors and has been appointed Vice Chair.
2009 Rate Application
On May 27, 2008 NSPI filed a rate application with the Nova Scotia Utility
and Review Board requesting an overall rate increase of 11.9% effective
January 1, 2009. In September 2008, NSPI reached a settlement agreement with
stakeholders regarding the company's 2009 rate application. The UARB approved
the settlement agreement in November 2008 which includes an average rate
increase of 9.4% for most customer segments effective January 1, 2009. The
approved settlement agreement also includes a Fuel Adjustment Mechanism
("FAM") effective January 1, 2009 and reduces NSPI's allowed earnings band to
9.1% to 9.6% with 9.35% used to set rates.
2007 Rate Decision
In February 2007 the UARB approved an average increase in electricity
rates of 3.8% effective April 1, 2007. The rate increase was part of a first
ever rate settlement agreement between NSPI and key stakeholders. NSPI's
allowed earnings band was unchanged at 9.3% to 9.8%.
Review of 2008
NSPI Q3 Net Earnings
millions of dollars (except Three months ended Nine months ended
earnings per common share) September 30 September 30
-------------------------------------------------------------------------
2008 2007 2008 2007
-------------------------------------------------------------------------
Electric revenue $250.6 $249.2 $830.4 $818.9
-------------------------------------------------------------------------
Fuel for generation and
purchased power 133.0 94.5 331.9 323.4
Operating, maintenance and general 52.4 50.1 151.4 150.7
Provincial grants and taxes 10.4 10.2 30.9 30.3
Depreciation 33.3 32.8 99.8 98.0
Regulatory amortization 3.7 5.6 11.3 12.7
Other revenue (3.7) (3.2) (12.0) (8.0)
-------------------------------------------------------------------------
Earnings from operations 21.5 59.2 217.1 211.8
Financing charges 24.3 34.7 86.5 98.3
-------------------------------------------------------------------------
(Loss) earnings before income
taxes (2.8) 24.5 130.6 113.5
Income taxes (5.1) (0.5) 39.4 38.5
-------------------------------------------------------------------------
Contribution to consolidated net
earnings $2.3 $25.0 $91.2 $75.0
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Contribution to consolidated
earnings per common share $0.02 $0.22 $0.82 $0.67
-------------------------------------------------------------------------
-------------------------------------------------------------------------
NSPI's contribution to consolidated net earnings decreased $22.7 million
to $2.3 million in Q3 2008 compared to $25.0 million in Q3 2007. Year-to-date,
NSPI's contribution to consolidated net earnings increased $16.2 million to
$91.2 million in 2008 compared to $75.0 million in 2007. Highlights of the
earnings changes are summarized in the following table:
Three months Nine months
ended ended
millions of dollars September 30 September 30
-------------------------------------------------------------------------
Contribution to consolidated net earnings -
2007 $25.0 $75.0
Increased year-to-date electric revenue due
to an electricity price increase on April 1,
2007 1.4 11.5
Increased fuel expense (38.5) (8.5)
Decreased financing charges due to lower
interest expense and foreign exchange gains
on USD denominated monetary net assets
compared to foreign exchange losses in 2007 10.4 11.8
Decreased income taxes in Q3 as discussed
below; year-to-date increased income taxes
due to higher taxable income partially
offset by increased deductions for capital
items 4.6 (0.9)
Other (0.6) 2.3
-------------------------------------------------------------------------
Contribution to consolidated net earnings -
2008 $2.3 $91.2
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Decreased income taxes in Q3 are due to lower taxable income and tax
recoveries of $3.0 million relating to a prior year. In Q3 2007, NSPI recorded
a tax recovery of $10.8 million relating to prior periods.
Electric Revenue
Q3 Electric Sales Volume Q3 Electric Sales Revenues
Gigawatt hours ("GWh") millions of dollars
----------------------------------- -----------------------------------
2008 2007 2006 2008 2007 2006
----------------------------------- -----------------------------------
Residential 786 771 763 Residential $97.8 $95.8 $90.1
Commercial 760 747 743 Commercial 73.5 72.7 70.0
Industrial 1,081 1,089 675 Industrial 69.4 70.0 44.8
Other 76 93 180 Other 9.9 10.7 15.0
----------------------------------- -----------------------------------
Total 2,703 2,700 2,361 Total $250.6 $249.2 $219.9
----------------------------------- -----------------------------------
----------------------------------- -----------------------------------
Year-to-date ("YTD")
Electric Sales Volume YTD Electric Sales Revenues
GWh millions of dollars
----------------------------------- -----------------------------------
2008 2007 2006 2008 2007 2006
----------------------------------- -----------------------------------
Residential 3,086 3,081 2,911 Residential $367.2 $359.9 $324.4
Commercial 2,345 2,368 2,281 Commercial 228.3 229.1 213.2
Industrial 3,157 3,145 1,949 Industrial 203.9 199.1 126.3
Other 250 266 565 Other 31.0 30.8 46.1
----------------------------------- -----------------------------------
Total 8,838 8,860 7,706 Total $830.4 $818.9 $710.0
----------------------------------- -----------------------------------
----------------------------------- -----------------------------------
Q3 Average Revenue /
Megawatt hour ("MWh")
-----------------------------------
2008 2007 2006
-----------------------------------
Dollars per
MWh $93 $92 $93
-----------------------------------
-----------------------------------
YTD Average Revenue / MWh
-----------------------------------
2008 2007 2006
-----------------------------------
Dollars per
MWh $94 $92 $92
-----------------------------------
-----------------------------------
Electric revenues increased by $1.4 million to $250.6 million in Q3 2008
compared to $249.2 million in Q3 2007. Year-to-date, electric revenues
increased by $11.5 million to $830.4 million in 2008 from $818.9 million in
2007 due to a 3.8% rate increase effective April 1, 2007.
Fuel for Generation and Purchased Power
Q3 Production Volume YTD Production Volume
GWh GWh
----------------------------------- -----------------------------------
2008 2007 2006 2008 2007 2006
----------------------------------- -----------------------------------
Coal & Coal &
petcoke 2,153 2,292 2,121 petcoke 6,832 7,042 6,760
Natural gas 321 315 122 Natural gas 1,009 724 262
Oil 27 4 - Oil 121 470 257
Renewable 181 152 205 Renewable 811 693 765
Purchased Purchased
power 169 105 78 power 593 465 225
----------------------------------- -----------------------------------
Total 2,851 2,868 2,526 Total 9,366 9,394 8,269
----------------------------------- -----------------------------------
----------------------------------- -----------------------------------
Purchased power includes 25 GWh of Purchased power includes 104 GWh of
renewables in Q3 2008 renewables in 2008
(2007 - 27 GWh; 2006 - 20 GWh). (2007 - 111 GWh; 2006 - 76 GWh).
Q3 Average Unit Fuel Costs
-----------------------------------
2008 2007 2006
-----------------------------------
Dollars per
MWh $47 $33 $27
-----------------------------------
-----------------------------------
YTD Average Unit Fuel Costs
-----------------------------------
2008 2007 2006
-----------------------------------
Dollars per
MWh $35 $34 $25
-----------------------------------
-----------------------------------
Fuel for generation and purchased power increased $38.5 million to $133.0
million in Q3 2008 compared to $94.5 million in Q3 2007. Year-to-date, fuel
for generation and purchased power increased $8.5 million to $331.9 million in
2008 compared to $323.4 million in 2007. Highlights of the changes are
summarized in the following table:
Three months Nine months
ended ended
millions of dollars September 30 September 30
-------------------------------------------------------------------------
Fuel for generation and purchased power - 2007 $94.5 $323.4
Increased commodity prices in Q3 primarily due
to increased coal prices; year-to-date the
increase in coal prices was offset by the
economic use of natural gas and favourable
hedge positions as a result of this fuel switch 15.3 (0.5)
Decreased valuation of the long-term receivable
(see discussion below) 16.8 1.9
Increased hydro production (2.2) (8.9)
Changes in generation mix 9.4 14.6
Other (0.8) 1.4
-------------------------------------------------------------------------
Fuel for generation and purchased power - 2008 $133.0 $331.9
-------------------------------------------------------------------------
-------------------------------------------------------------------------
The valuation of the long-term receivable from a natural gas supplier
requires NSPI to utilize a combination of historical and future natural gas
prices. NSPI uses market-based forward indices when determining future prices.
Future prices can change from period to period which will cause a
corresponding change in the value of the long-term receivable. In Q2, NSPI had
a positive revaluation of $14.7 million which reduced fuel costs. Weakening
forward gas prices has reversed this revaluation in the quarter and the
year-to-date net effect is an increase in fuel costs of $1.9 million.
Outlook
One of NSPI's fuel suppliers provided notice in December 2007 that it was
suspending shipments pending a review of the contract. NSPI has initiated
arbitration proceedings to enforce its rights under the contract. Fuel costs
are expected to be higher for the balance of 2008 compared to 2007.
The company's outlook is to earn within its allowed return on equity range
for 2008 given the company's favourable year-to-date results and consistent
with NSPI's 2007 rate settlement agreement.
BANGOR HYDRO-ELECTRIC COMPANY
All amounts in the Bangor Hydro section are reported in US dollars unless
otherwise stated.
Overview
BHE's core business is the transmission and distribution ("T&D") of
electricity. Electricity generation is deregulated in Maine, and several
suppliers compete to provide customers with the energy that is delivered
through the BHE T&D network. BHE is a cost of service utility.
Review of 2008
Bangor Hydro Q3 Net Earnings
millions of dollars (except Three months ended Nine months ended
earnings per common share) September 30 September 30
-------------------------------------------------------------------------
2008 2007 2008 2007
-------------------------------------------------------------------------
T&D electric revenues $25.2 $25.3 $71.7 $75.8
Resale of purchased power 3.2 3.1 13.3 10.9
Transmission pool revenue 5.8 6.2 15.0 8.2
-------------------------------------------------------------------------
Total revenue 34.2 34.6 100.0 94.9
Purchased power and fuel for
generation 7.3 7.2 24.1 23.6
Operating, maintenance and general 7.3 6.3 21.0 18.3
Property taxes 1.4 1.0 4.1 4.0
Depreciation 3.8 3.3 11.4 9.8
Regulatory amortization 2.3 3.6 7.5 10.0
Other (0.8) (0.4) (3.1) (1.3)
-------------------------------------------------------------------------
Earnings from operations 12.9 13.6 35.0 30.5
Financing charges 2.7 0.5 8.5 2.0
-------------------------------------------------------------------------
Earnings before income taxes 10.2 13.1 26.5 28.5
Income taxes 4.0 4.4 10.3 9.5
-------------------------------------------------------------------------
Contribution to consolidated net
earnings - USD $6.2 $8.7 $16.2 $19.0
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Contribution to consolidated net
earnings - CAD $6.5 $9.1 $16.5 $20.8
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Contribution to consolidated
earnings per common share - CAD $0.05 $0.09 $0.14 $0.19
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Net earnings weighted average
foreign exchange rate - CAD/USD $1.04 $1.04 $1.02 $1.09
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Bangor Hydro's contribution to consolidated net earnings decreased by $2.5
million to $6.2 million in Q3 2008 compared to $8.7 million in Q3 2007.
Year-to-date, Bangor Hydro's contribution to consolidated net earnings
decreased by $2.8 million to $16.2 million in 2008 compared to $19.0 million
in 2007. Highlights of the earnings changes are summarized in the following
table:
Three months Nine months
ended ended
millions of dollars September 30 September 30
-------------------------------------------------------------------------
Contribution to consolidated net earnings -
2007 $8.7 $19.0
Year-to-date increase in net transmission pool
revenue associated with the recovery of the
NRI transmission line from the New England
Power Pool beginning in June 2007 (0.4) 6.8
Decreased overheads and allowance for funds
used during construction capitalized primarily
as a result of completing the NRI transmission
line in Q4 2007 (3.1) (8.3)
Increased interest expense and depreciation
primarily related to the NRI transmission line (0.8) (2.6)
Other 1.8 1.3
-------------------------------------------------------------------------
Contribution to consolidated net earnings -
2008 $6.2 $16.2
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Bangor Hydro's decreased year-to-date contribution to consolidated net
earnings in CAD was also due to the $1.2 million effect of the stronger
Canadian dollar.
Electric Revenue
Q3 Electric Sales Volume Q3 Electric Sales Revenues
GWh millions of dollars
----------------------------------- -----------------------------------
2008 2007 2006 2008 2007 2006
----------------------------------- -----------------------------------
Residential 144 141 144 Residential $12.0 $11.7 $12.1
Commercial 160 161 164 Commercial 9.3 9.5 9.8
Industrial 93 103 91 Industrial 2.8 2.7 2.6
Other 3 3 3 Other 1.1 1.4 2.0
----------------------------------- -----------------------------------
Total 400 408 402 Total $25.2 $25.3 $26.5
----------------------------------- -----------------------------------
----------------------------------- -----------------------------------
YTD Electric Sales Volume YTD Electric Sales Revenues
GWh millions of dollars
----------------------------------- -----------------------------------
2008 2007 2006 2008 2007 2006
----------------------------------- -----------------------------------
Residential 436 437 434 Residential $34.8 $36.6 $36.2
Commercial 459 457 457 Commercial 25.8 27.5 27.3
Industrial 260 277 279 Industrial 7.0 8.4 8.5
Other 8 9 9 Other 4.1 3.3 4.3
----------------------------------- -----------------------------------
Total 1,163 1,180 1,179 Total $71.7 $75.8 $76.3
----------------------------------- -----------------------------------
----------------------------------- -----------------------------------
Q3 Average Revenue / MWh
-----------------------------------
2008 2007 2006
-----------------------------------
Dollars per
MWh $63 $62 $66
-----------------------------------
-----------------------------------
YTD Average Revenue / MWh
-----------------------------------
2008 2007 2006
-----------------------------------
Dollars per
MWh $62 $64 $65
-----------------------------------
-----------------------------------
The changes in average revenue per MWh in 2008 compared to 2007 reflect
the July 1, 2007 reduction in transmission rates and the March 1, 2008
reduction in stranded cost rates, offset by the January 1, 2008 increase in
distribution rates and the July 1, 2008 increase in transmission rates.
OTHER
All activities of Emera other than its two wholly-owned regulated electric
utilities are incorporated into Other, including:
- Bear Swamp, a 50/50 joint venture in a 600 megawatt pumped storage
hydro-electric facility in northern Massachusetts. Bear Swamp typically
pumps water into its reservoir using lower priced off-peak power, and
uses that hydro capacity to generate electricity during higher priced
on-peak periods.
- Emera Energy Services, a physical energy business which purchases and
sells natural gas and electricity and provides related energy asset
management services. Emera Energy Services operates with minimal
day-to-day commodity risk exposure. Volatility in natural gas markets
and electricity markets usually results in increased opportunities for
Emera Energy Services.
- Brunswick Pipeline, a 145 kilometer pipeline currently under
construction that will deliver natural gas from the Canaport(TM)
Liquefied Natural Gas import terminal, also under construction, near
Saint John, New Brunswick, to markets in Canada and the US northeast.
- A 12.9% interest in the $2 billion, 1,400 kilometer Maritimes &
Northeast Pipeline that transports Nova Scotia's offshore natural gas
to markets in Maritime Canada and the northeastern United States.
- A 19% interest in Lucelec, a vertically integrated electric utility on
the Caribbean Island of St. Lucia, which was acquired in January 2007.
- A 7.35% interest in OpenHydro, an Irish renewable tidal energy company,
which was acquired in February 2008.
- A 25% interest in GBPC, a vertically integrated utility serving
19,000 customers on Grand Bahama Island, which was acquired in
September 2008.
- Certain corporate-wide functions such as executive management,
strategic planning, treasury services, tax planning, business
development, and corporate governance; and financing for the
corporation's business outside of its regulated electric utilities.
Brunswick Pipeline Capital Costs
Brunswick Pipeline construction is progressing and is expected to be
completed as targeted during Q4 2008. The horizontal directional drill under
the St. John River was successfully completed in September. Capital costs are
expected to be $465 million.
M&NP Capital Contributions
During Q3, M&NP repaid its outstanding debt related to the US portion of
the pipeline through equity contributions from the partners, which M&NP will
return to the partners once new financing is in place. The Company's portion
of the equity contribution was $46.5 million USD ($47.0 million CAD).
Review of 2008
Bear Swamp, Emera Energy Services and Brunswick Pipeline are reported on
an earnings before interest and income taxes basis ("EBIT"), and M&NP and
Lucelec are reported on an equity basis.
Other Q3 Earnings
millions of dollars (except Three months ended Nine months ended
earnings per common share) September 30 September 30
-------------------------------------------------------------------------
2008 2007 2008 2007
-------------------------------------------------------------------------
Bear Swamp - operational $4.9 $4.1 $13.4 $9.9
Bear Swamp - mark-to-market (12.4) 1.0 (2.1) 5.2
Emera Energy Services 0.5 2.3 5.5 10.3
M&NP 2.4 2.1 7.6 8.0
Lucelec 0.6 0.5 1.5 1.3
Brunswick Pipeline 4.4 - 8.6 -
Corporate costs and other (1.4) (2.3) (10.1) (9.6)
-------------------------------------------------------------------------
(1.0) 7.7 24.4 25.1
Interest expense 5.9 0.8 12.2 5.0
-------------------------------------------------------------------------
Earnings before income taxes (6.9) 6.9 12.2 20.1
Income taxes (4.6) 0.1 1.1 1.2
-------------------------------------------------------------------------
Contribution to consolidated
net earnings $(2.3) $6.8 $11.1 $18.9
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Contribution to consolidated
earnings per common share $(0.02) $0.06 $0.10 $0.17
-------------------------------------------------------------------------
-------------------------------------------------------------------------
The contribution of Other to consolidated net earnings decreased $9.1
million to $(2.3) million in Q3 2008 compared to $6.8 million in Q3 2007.
Year-to-date, the contribution of Other to consolidated net earnings decreased
$7.8 million to $11.1 million in 2008 compared to $18.9 million in 2007.
Highlights of the earnings changes are summarized in the following table:
Three months Nine months
ended ended
millions of dollars September 30 September 30
-------------------------------------------------------------------------
Contribution to consolidated net earnings -
2007 $6.8 $18.9
Increased Bear Swamp - operational due to
increased energy and capacity sales 0.8 3.5
Decreased Bear Swamp - mark-to-market due to
an unfavourable commodity price position (13.4) (7.3)
Decreased Emera Energy Services primarily due
to reduced activity (1.8) (4.8)
Increased Brunswick Pipeline due to AFUDC on
construction of the pipeline 4.4 8.6
Increased interest due to increased short-term
debt used to finance the construction of
Brunswick Pipeline and foreign exchange gains
in 2007 (5.1) (7.2)
Decreased income taxes 4.7 0.1
Other 1.3 (0.7)
-------------------------------------------------------------------------
Contribution to consolidated net earnings -
2008 $(2.3) $11.1
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Consolidated Balance Sheets
Significant changes in the consolidated balance sheets between September
30, 2008 and December 31, 2007 include:
Increase
millions of dollars (Decrease) Explanation
-------------------------------------------------------------------------
Assets
-------------------------------------------------------------------------
Inventory 15.6 Increased fuel inventory levels.
-------------------------------------------------------------------------
Prepaid expenses 20.7 Timing of provincial grants in lieu of
taxes and insurance payments, and
increased posted margin paid to
counterparties.
-------------------------------------------------------------------------
Derivatives in a valid 48.6 Favourable USD and commodity price
hedging relationship positions. The effective portion of the
(including long-term change is recognized in accumulated
portion) other comprehensive income.
-------------------------------------------------------------------------
Held-for-trading (27.6) Unfavourable commodity price positions.
derivatives (including The portion related to NSPI's
long-term portion) regulatory liabilities is recognized in
deferred credits.
-------------------------------------------------------------------------
Long-term receivable 43.6 Increased receivable from a natural gas
supplier.
-------------------------------------------------------------------------
Deferred charges (31.7) Reduction in accounts receivable
securitization, decreased pension
asset, ongoing regulatory
amortizations, and a decrease in
deferred fuel switching derivatives.
-------------------------------------------------------------------------
Investments subject to 163.1 Additional investment in MN&P,
significant influence investment in ICDU, and equity
earnings. The non-controlling interest
in ICDU is reflected in non-controlling
interest below.
-------------------------------------------------------------------------
Available-for-sale 15.0 Investment in OpenHydro.
investments
-------------------------------------------------------------------------
Property, plant & 349.2 Primarily capital spending in
equipment and Brunswick Pipeline.
construction work in
progress
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Liabilities and
Shareholders' Equity
-------------------------------------------------------------------------
Accounts payable 38.5 Primarily spending in Brunswick
Pipeline.
-------------------------------------------------------------------------
Derivatives in a valid (32.4) Favourable USD positions. The effective
hedging relationship portion of the change is recognized
(including long-term in accumulated other comprehensive
portion) income.
-------------------------------------------------------------------------
Future income tax 10.1 Increased timing differences relating
liabilities to depreciable assets.
-------------------------------------------------------------------------
Deferred credits (25.2) Decreased regulatory liability related
to held-for-trading natural gas
contracts.
-------------------------------------------------------------------------
Short-term debt and 390.8 Primarily increased short-term debt
long-term debt to finance Brunswick Pipeline.
(including current
portion)
-------------------------------------------------------------------------
Non-controlling 40.8 Investment in ICDU.
interest
-------------------------------------------------------------------------
Common shares 12.9 Shares issued under purchase plans and
stock options exercised.
-------------------------------------------------------------------------
Accumulated other 113.7 Primarily represents changes in USD
comprehensive income and commodity price hedge positions,
and the favourable effect of the
Canadian dollar on the company's
investment in Bangor Hydro.
-------------------------------------------------------------------------
Retained earnings 36.0 Net earnings in excess of dividends
paid.
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Outstanding Share Data
Common Share
Capital
Millions of millions
Issued and Outstanding: Shares of dollars
-------------------------------------------------------------------------
December 31, 2006 110.93 $1,055.2
Issued for cash under purchase plans 0.45 9.0
Options exercised under senior management
share option plan 0.09 1.7
Share-based compensation - 0.3
-------------------------------------------------------------------------
December 31, 2007 111.47 $1,066.2
Issued for cash under purchase plans 0.30 6.1
Options exercised under senior management
share option plan 0.33 6.1
Share-based compensation - 0.7
-------------------------------------------------------------------------
September 30, 2008 112.10 $1,079.1
-------------------------------------------------------------------------
-------------------------------------------------------------------------
As at October 24, 2008 the number of issued and outstanding common shares
was 112.13 million.
Liquidity and Capital Resources
In Q1 2008, Emera and Nova Scotia Power completed final filings of debt
shelf prospectuses in the amount of $400 million for each company that will
provide the companies with access to long-term debt. The company also has
access to equity capital markets for both common and preferred shares.
In Q3 2008, Moody's Investors Service ("Moody's") confirmed the credit
ratings of Emera and Nova Scotia Power and revised the rating outlook from
negative to stable for both companies. The revision reflects Moody's view that
NSPI has been successful in improving its relationships with key stakeholders
and the UARB. Moody's also expects that NSPI's exposure to regulatory risk
will be reduced and that there is less likelihood of variability in NSPI's
financial results following implementation of the FAM.
North American financial markets experienced significant volatility in the
quarter which has pressured global debt markets. Nova Scotia Power issues
commercial paper, 100% backed by a syndicated bank line of credit, to finance
short-term cash requirements and has been able to continue to access the
market as required. The company has sufficient unutilized borrowing capacity
to continue to meet cash flow requirements. To date, the company has not
incurred any significant incremental costs during the market disruption. The
pressure on global debt markets may affect the credit worthiness of certain
counterparties of Emera and its subsidiaries. Emera continues to perform
regular credit risk assessments on its counterparties and deposits are
required on any high risk accounts.
On October 3, 2008, Emera entered into a $200 million non-revolving bridge
credit facility ("bridge facility"), maturing June 30, 2009. The amount of the
bridge facility is required to be reduced by the proceeds of any debt or
equity issuance by Emera.
Consolidated Cash Flow Highlights
Significant changes in the consolidated cash flow statements between
September 30, 2008 and 2007 include:
Three months ended
September 30
millions of dollars 2008 2007 Explanation
-------------------------------------------------------------------------
Cash and cash equivalents, $108.7 $8.3
beginning of period
-------------------------------------------------------------------------
Provided by (used in):
Operating activities 40.1 79.5 In 2008, cash earnings
partially offset by
increased non-cash working
capital.
-----------------------------
In 2007, cash earnings
partially offset by
increased non-cash working
capital.
-------------------------------------------------------------------------
Investing activities (286.3) (82.4) In 2008, capital spending,
including Brunswick
Pipeline, additional
investment in M&NP, and
acquisition of a
50% interest in ICDU.
-----------------------------
In 2007, capital spending,
including the NRI
transmission line and
Brunswick Pipeline.
-------------------------------------------------------------------------
Financing activities 166.0 3.2 In 2008, increased debt
levels, partially offset by
dividends on common shares.
-----------------------------
In 2007, increased debt
levels offset by dividends
on common shares.
-------------------------------------------------------------------------
Cash and cash equivalents, $28.5 $8.6
end of period
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Nine months ended
September 30
millions of dollars 2008 2007 Explanation
-------------------------------------------------------------------------
Cash and cash equivalents, $26.4 $19.5
beginning of period
-------------------------------------------------------------------------
Provided by (used in):
Operating activities 254.3 143.6 In 2008, cash earnings.
-----------------------------
In 2007, cash earnings
partially offset by
increased non-cash working
capital.
-------------------------------------------------------------------------
Investing activities (524.9) (205.6) In 2008, capital spending,
including Brunswick
Pipeline, and acquisition of
a 7.35% interest in
OpenHydro and a 50% interest
in ICDU.
-----------------------------
In 2007, capital spending,
including the NRI
transmission line and
Brunswick Pipeline, and
acquisition of a
19% interest in Lucelec.
-------------------------------------------------------------------------
Financing activities 272.7 51.1 In 2008, increased debt
levels, partially offset by
dividends on common shares
and decreased accounts
receivable securitized.
-----------------------------
In 2007, increased debt
levels, partially offset by
dividends on common shares
and decreased accounts
receivable securitized.
-------------------------------------------------------------------------
Cash and cash equivalents, $28.5 $8.6
end of period
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Financial and Commodity Instruments
The company enters into swap contracts on commodities to limit exposure to
(hedge) fluctuations in commodity prices; foreign exchange forwards, options
and swap contracts to hedge currency rate fluctuations; and interest rate
contracts to hedge interest rate fluctuations. In addition, the company has
contracts for physical purchases and sales of natural gas. Collectively, these
contracts are referred to as derivatives.
Derivatives that meet stringent documentation requirements, and can be
proven to be effective hedges both at the inception and over the term of the
derivative qualify for hedge accounting. That enables amounts paid or received
to be deferred and recognized in earnings in the same period that the related
hedged item is realized.
Where the documentation or effectiveness requirements are not met, the
derivative instruments are recognized at fair value with any changes in fair
value recognized in net earnings in the reporting period.
Held-for-trading derivatives are recorded on the balance sheet at fair
value, with changes normally recorded in net earnings of the period, unless
deferred as a result of regulatory accounting.
Hedging Items Recognized on the Balance Sheet
The company has the following categories on the balance sheet related to
derivatives in valid hedging relationships:
-------------------------------------------------------------------------
September 30 December 31
millions of dollars 2008 2007
-------------------------------------------------------------------------
Inventory - $7.6
Derivatives in a valid hedging relationship $27.0 (54.0)
Long-term debt 0.4 0.6
-------------------------------------------------------------------------
$27.4 $(45.8)
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Hedging Impact Recognized in Earnings
For the three and nine month periods ended September 30, the impacts of
derivatives in valid hedging relationships recognized in earnings were
recorded in the following categories:
Three months ended Nine months ended
millions of dollars September 30 September 30
-------------------------------------------------------------------------
2008 2007 2008 2007
-------------------------------------------------------------------------
Fuel and purchased power decrease
(increase) $1.3 $(5.3) $14.4 $(10.4)
-------------------------------------------------------------------------
Hedging earnings impact $1.3 $(5.3) $14.4 $(10.4)
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Held-for-trading Items Recognized on the Balance Sheet
The company has recognized a net unrealized fair value of held-for-trading
derivatives asset of $85.5 million as at September 30, 2008 (December 31, 2007
- $110.7 million) on the balance sheet.
Held-for-trading Gains (Losses) Recognized in Earnings
The company has recognized the following realized and unrealized gains and
losses with respect to held-for-trading derivatives in earnings:
Three months ended Nine months ended
millions of dollars September 30 September 30
-------------------------------------------------------------------------
2008 2007 2008 2007
-------------------------------------------------------------------------
Electric revenue $0.8 $(1.5) $2.2 $0.9
Other revenue (9.8) 6.5 8.6 19.6
Fuel and purchased power (1.3) 2.1 (0.1) (0.5)
Interest (0.1) - (0.4) -
-------------------------------------------------------------------------
Held-for-trading (losses) gains $(10.4) $7.1 $10.3 $20.0
-------------------------------------------------------------------------
-------------------------------------------------------------------------
In determining the fair value of derivative financial instruments, the
company has relied on quoted market prices as at the reporting date.
Transactions with Related Parties
In the ordinary course of business, Emera purchased natural gas
transportation capacity totaling $8.1 million (2007 - $5.9 million) during the
three months ended September 30, 2008 and $22.4 million (2007 - $20.3 million)
during the nine months ended September 30, 2008 from the Maritimes & Northeast
Pipeline, an investment under significant influence of the company. The amount
is recognized in fuel for generation and purchased power or netted against
energy marketing margin in other revenue, and is measured at the exchange
amount. As at September 30, 2008 the amount payable to the related party is
$4.2 million (December 31, 2007 - $4.5 million), is non-interest bearing and
is under normal credit terms.
Changes in Accounting Policies
The Canadian Institute of Chartered Accountants ("CICA") has issued new
accounting standards 1535 Capital Disclosures, 3031 Inventories, 3862
Financial Instruments - Disclosures, and 3863 Financial Instruments -
Presentation which are applicable to Emera's 2008 fiscal year. The following
provides more information on each new accounting standard.
Capital Disclosures: This new standard requires disclosure of the
company's objectives, policies, and processes for managing capital;
quantitative data about what the company regards as capital; whether the
company has complied with any externally imposed capital requirements; and, if
the company has not complied, the consequences of such non-compliance. The new
accounting standard covers disclosure only and had no effect on the financial
results of the company. Further information can be found in note 10 to the
financial statements.
Financial Instruments - Disclosures, and Financial Instruments -
Presentation: These new standards replace accounting standard 3861 Financial
Instruments - Disclosure and Presentation. Presentation requirements have not
changed. Enhanced disclosure is required to assist users of the financial
statements in evaluating the significance of financial instruments on the
company's financial position and performance, including qualitative and
quantitative information about the company's exposure to risks arising from
financial instruments. The new accounting standards cover disclosure only and
had no effect on the financial results of the company. Further information can
be found in note 11 to the financial statements.
Inventories: The new standard provides more guidance on the measurement
and disclosure requirements for inventories than the previous standard, 3030
Inventories. Specifically, the new standard requires that inventories be
measured at the lower of cost and net realizable value, and provides more
guidance on the determination of cost and its subsequent recognition as an
expense, including any write-down to net realizable value. The company
previously measured inventories at the lower of cost and market. The company
uses the weighted average method to determine the cost of inventory.
The company has applied the new standard retrospectively without
restatement, which resulted in a decrease to inventory and retained earnings
of $3.3 million as at January 1, 2008.
The change in inventory is due to the following:
Fuel inventory Materials inventory
Nine months ended Nine months ended
September 30 September 30
-------------------------------------------------------------------------
millions of dollars 2008 2007 2008 2007
-------------------------------------------------------------------------
Inventory, beginning of period $67.7 $81.2 $32.1 $32.4
-------------------------------------------------------------------------
Accounting policy change - - (3.3) -
-------------------------------------------------------------------------
Purchases 258.3 243.8 29.5 29.9
-------------------------------------------------------------------------
Write-down of inventory to net
realizable value - - (0.9) -
-------------------------------------------------------------------------
Inventories expensed (239.3) (253.3) (12.8) (13.0)
-------------------------------------------------------------------------
Inventories capitalized - - (17.3) (17.4)
-------------------------------------------------------------------------
Other - - 1.3 1.3
-------------------------------------------------------------------------
Inventory, end of period $86.7 $71.7 $28.6 $33.2
-------------------------------------------------------------------------
-------------------------------------------------------------------------
The company has not pledged inventory as security for liabilities.
Future Accounting Policy Changes
Changeover to International Financial Reporting Standards ("IFRS"): In
April 2008, the CICA issued an IFRS Omnibus Exposure Draft which proposes that
publicly accountable enterprises be required to apply IFRS effective for
Emera's 2011 fiscal year with consistent comparative information required for
2010. The company is currently assessing the effect of IFRS on its financial
statements and developing its changeover plan.
Goodwill and Intangible Assets: In February 2008, the CICA issued Section
3064 Goodwill and Intangible Assets ("3064") applicable to Emera's 2009 fiscal
year, replacing Section 3062 Goodwill and Other Intangible Assets. The
goodwill requirements have not changed. The requirements for intangible assets
now clarify that costs may only be deferred when they relate to an item that
meets the definition of an asset. An intangible asset must be identifiable; be
a resource over which the company has control; probably generate future
economic benefits; and have a reliably measurable cost. The company is
currently assessing the effect of 3064 on its financial statements but does
not expect a material change.
Dividends
The Board of Directors has approved two increases to the quarterly
dividend in 2008. In October 2008, the Board of Directors approved a quarterly
dividend increase to $0.2525 per common share, reflecting an increase on an
annualized basis to $1.01 per common share. In January 2008, the Board of
Directors approved a quarterly dividend increase to $0.2375 per common share,
reflecting an increase on an annualized basis to $0.95 per common share.
Summary of Quarterly Reports
For the quarter ended
millions of dollars (except earnings per common share)
-------------------------------------------------------------------------
Q3 Q2 Q1 Q4 Q3 Q2 Q1 Q4
2008 2008 2008 2007 2007 2007 2007 2006
-------------------------------------------------------------------------
Total
revenues $295.8 $317.6 $381.2 $343.9 $310.3 $325.4 $359.9 $307.0
-------------------------------------------------------------------------
Net
earnings
applicable
to common
shares 6.5 42.9 69.4 36.6 40.9 34.1 39.7 33.5
-------------------------------------------------------------------------
Earnings
per common
share -
basic 0.05 0.39 0.62 0.33 0.37 0.30 0.36 0.30
-------------------------------------------------------------------------
Earnings
per common
share -
diluted 0.05 0.37 0.58 0.32 0.35 0.30 0.35 0.30
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Quarterly total revenues and net earnings applicable to common shares are
affected by seasonality, with Q1 and Q4 the strongest periods, reflecting
colder weather and fewer daylight hours at those times of year.
Financial Statements
Consolidated Statements of Earnings (Unaudited)
-------------------------------------------------------------------------
For the
millions of dollars (except Three months ended Nine months ended
earnings per common share) September 30 September 30
-------------------------------------------------------------------------
2008 2007 2008 2007
-------------------------------------------------------------------------
Revenue
Electric $293.5 $290.3 $950.2 $947.5
Other 2.3 20.0 44.4 48.1
-------------------------------------------------------------------------
295.8 310.3 994.6 995.6
-------------------------------------------------------------------------
Cost of operations
Fuel for generation and
purchased power 146.4 109.5 371.1 370.5
Operating, maintenance
and general 66.7 64.9 195.8 193.3
Provincial, state, and
municipal taxes 12.7 11.6 37.2 36.1
Depreciation 37.5 36.8 112.3 111.2
Regulatory amortization 6.2 9.2 19.0 23.6
-------------------------------------------------------------------------
269.5 232.0 735.4 734.7
-------------------------------------------------------------------------
Earnings from operations 26.3 78.3 259.2 260.9
Financing charges (note 6) 28.2 35.8 98.4 105.3
Equity earnings 3.0 2.6 9.1 9.3
-------------------------------------------------------------------------
Earnings before income taxes 1.1 45.1 169.9 164.9
Income taxes (note 7) (5.4) 4.2 51.1 50.2
-------------------------------------------------------------------------
Net earnings applicable to
common shares $6.5 $40.9 $118.8 $114.7
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Earnings per common share - basic $0.05 $0.37 $1.06 $1.03
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Earnings per common share - diluted $0.05 $0.35 $1.04 $1.00
-------------------------------------------------------------------------
-------------------------------------------------------------------------
See accompanying notes to the unaudited consolidated financial
statements.
Weighted average number of common
shares outstanding (millions)
- basic 112.0 111.3 111.8 111.2
- diluted (note 12) 113.1 125.1 124.7 124.5
Consolidated Balance Sheets (Unaudited)
-------------------------------------------------------------------------
As at September 30 December 31
millions of dollars 2008 2007
-------------------------------------------------------------------------
Assets
Current assets
Cash and cash equivalents $28.5 $26.4
Restricted cash - 1.0
Accounts receivable 267.0 274.2
Income tax receivable 7.7 13.7
Inventory (note 3) 115.3 99.7
Prepaid expenses 77.6 56.9
Future income tax assets 4.2 6.7
Derivatives in a valid hedging relationship 18.7 12.2
Held-for-trading derivatives 68.1 76.2
-------------------------------------------------------------------------
587.1 567.0
-------------------------------------------------------------------------
Long-term receivable 51.3 7.7
-------------------------------------------------------------------------
Derivatives in a valid hedging relationship 53.1 11.0
-------------------------------------------------------------------------
Held-for-trading derivatives 44.1 63.6
-------------------------------------------------------------------------
Deferred charges (note 8) 385.6 417.3
-------------------------------------------------------------------------
Future income tax assets 13.5 16.2
-------------------------------------------------------------------------
Goodwill 88.4 82.8
-------------------------------------------------------------------------
Investments subject to significant influence 287.6 124.5
-------------------------------------------------------------------------
Available-for-sale investments 16.8 1.8
-------------------------------------------------------------------------
Property, plant and equipment 2,843.0 2,820.0
Construction work in progress 435.4 109.2
-------------------------------------------------------------------------
3,278.4 2,929.2
-------------------------------------------------------------------------
$4,805.9 $4,221.1
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Liabilities and Shareholders' Equity
Current liabilities
Current portion of long-term debt $130.0 $121.0
Current portion of preferred shares issued
by subsidiary 125.0 -
Short-term debt 492.8 104.6
Accounts payable and accrued charges 321.2 282.7
Income tax payable 1.6 3.2
Dividends payable 3.2 3.2
Future income tax liabilities 3.0 2.0
Derivatives in a valid hedging relationship 27.8 44.1
Held-for-trading derivatives 16.7 22.0
-------------------------------------------------------------------------
1,121.3 582.8
-------------------------------------------------------------------------
Derivatives in a valid hedging relationship 17.0 33.1
-------------------------------------------------------------------------
Held-for-trading derivatives 10.0 7.1
-------------------------------------------------------------------------
Future income tax liabilities 92.0 82.9
-------------------------------------------------------------------------
Asset retirement obligations 87.1 83.8
-------------------------------------------------------------------------
Deferred credits (note 8) 185.6 210.8
-------------------------------------------------------------------------
Long-term debt (note 9) 1,593.8 1,600.2
-------------------------------------------------------------------------
Preferred shares issued by subsidiary 135.0 260.0
-------------------------------------------------------------------------
Non-controlling interest 41.4 0.6
-------------------------------------------------------------------------
Shareholders' equity
Common shares (note 12) 1,079.1 1,066.2
Contributed surplus 3.3 3.0
Accumulated other comprehensive income (95.3) (209.0)
Retained earnings (note 3) 535.6 499.6
-------------------------------------------------------------------------
1,522.7 1,359.8
-------------------------------------------------------------------------
$4,805.9 $4,221.1
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Commitments (note 15)
See accompanying notes to the unaudited consolidated financial
statements.
Approved on behalf of the Board of Directors
"Derek Oland" "Christopher Huskilson"
Derek Oland, Christopher Huskilson,
Chairman President and Chief Executive Officer
Consolidated Statements of Cash Flow (Unaudited)
-------------------------------------------------------------------------
For the Three months ended Nine months ended
millions of dollars September 30 September 30
-------------------------------------------------------------------------
2008 2007 2008 2007
-------------------------------------------------------------------------
Operating activities
Net earnings applicable to common
shares $6.5 $40.9 $118.8 $114.7
Non-cash items:
Depreciation 37.5 36.8 112.3 111.2
Amortization of deferred charges 3.2 3.6 10.2 10.6
Equity earnings (3.0) (2.6) (9.1) (9.3)
Regulatory amortization 6.2 9.2 19.0 23.6
Allowance for funds used during
construction (6.1) (3.5) (12.4) (9.1)
Future income taxes (4.2) 1.3 8.6 5.2
Post-retirement benefits 3.3 4.0 8.3 11.1
Reduction in regulatory asset - 14.6 - 14.6
Other non-cash operating items 10.9 (6.1) (5.3) (13.0)
Other cash operating items 1.6 0.4 1.1 1.8
-------------------------------------------------------------------------
55.9 98.6 251.5 261.4
Change in non-cash operating
working capital (note 13) (15.8) (19.1) 2.8 (117.8)
-------------------------------------------------------------------------
Net cash provided by operating
activities 40.1 79.5 254.3 143.6
-------------------------------------------------------------------------
Investing activities
Property, plant and equipment (191.8) (81.9) (403.8) (176.9)
Acquisitions (note 14) (44.9) - (60.3) (25.7)
Retirement spending net of salvage (1.8) (0.7) (4.4) (2.2)
Decrease (increase) in restricted
cash 0.5 0.5 1.0 (0.5)
Investments (48.3) (0.3) (57.4) (0.3)
-------------------------------------------------------------------------
Net cash used in investing
activities (286.3) (82.4) (524.9) (205.6)
-------------------------------------------------------------------------
Financing activities
Retirement of long-term debt (119.8) (1.0) (120.8) (2.0)
Issuance of long-term debt - 50.2 - 117.0
Increase (decrease) in
short-term debt 308.7 (22.2) 486.3 59.2
Issuance of common shares 3.8 2.6 12.2 8.8
Dividends on common shares (26.6) (25.1) (79.6) (74.5)
Accounts receivable securitization - - (25.0) (55.0)
Other financing (0.1) (1.3) (0.4) (2.4)
-------------------------------------------------------------------------
Net cash provided by financing
activities 166.0 3.2 272.7 51.1
-------------------------------------------------------------------------
(Decrease) increase in cash and
cash equivalents (80.2) 0.3 2.1 (10.9)
Cash and cash equivalents,
beginning of period 108.7 8.3 26.4 19.5
-------------------------------------------------------------------------
Cash and cash equivalents,
end of period $28.5 $8.6 $28.5 $8.6
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Cash and cash equivalents
consists of:
Cash $5.8 $4.2 $5.8 $4.2
Cash equivalents 22.7 4.4 22.7 4.4
-------------------------------------------------------------------------
Cash and cash equivalents,
end of period $28.5 $8.6 $28.5 $8.6
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Supplemental disclosure
of cash paid:
Interest $35.1 $33.8 $99.8 $94.5
Income and capital taxes $13.5 $25.2 $47.0 $106.6
-------------------------------------------------------------------------
-------------------------------------------------------------------------
See accompanying notes to the unaudited consolidated financial
statements.
Consolidated Statements of Changes in Shareholders' Equity (Unaudited)
-------------------------------------------------------------------------
For the nine months ended Accumu-
September 30, 2008 lated
millions of dollars Other
Compre- Total
Contri- hensive AOCI and
Common buted Income Retained Retained
Shares Surplus ("AOCI") Earnings Earnings
-------------------------------------------------------------------------
Balance,
December 31, 2007 $1,066.2 $3.0 $(209.0) $499.6 $290.6
-------------------------------------------------------------------------
Accounting policy
change (note 3) - - - (3.3) (3.3)
-------------------------------------------------------------------------
Comprehensive Income:
Net earnings applicable
to common shares - - - 118.8 118.8
Net gain on derivatives
in a valid hedging
relationship - - 93.6 - 93.6
Reclassification of
hedging gains
included in income - - (14.9) - (14.9)
Reclassification of
hedging losses
included in inventory - - 7.6 - 7.6
Reclassification of
hedging gains included
in construction work
in progress - - (2.0) - (2.0)
Unrealized gain on
translation of
self-sustaining
foreign operations - - 29.9 - 29.9
Other - - (0.5) - (0.5)
-------------------------------------------------------------------------
Total comprehensive
income - - 113.7 118.8 232.5
-------------------------------------------------------------------------
Dividends declared on
common shares - - - (79.5) (79.5)
Common shares issued
under purchase plans 6.1 - - - -
Senior management stock
options exercised 6.1 (0.5) - - -
Stock option expense - 0.8 - - -
Other share-based
compensation 0.7 - - - -
-------------------------------------------------------------------------
Balance,
September 30, 2008 $1,079.1 $3.3 $(95.3) $535.6 $440.3
-------------------------------------------------------------------------
-------------------------------------------------------------------------
-------------------------------------------------------------------------
For the nine months ended Total
September 30, 2007 Contri- AOCI and
millions of dollars Common buted Retained Retained
Shares Surplus AOCI Earnings Earnings
-------------------------------------------------------------------------
Balance,
December 31, 2006 $1,055.2 $2.2 $(100.2) $450.9 $350.7
-------------------------------------------------------------------------
Accounting policy
change - - (5.3) (2.7) (8.0)
-------------------------------------------------------------------------
Comprehensive Income:
Net earnings applicable
to common shares - - - 114.7 114.7
Net loss on derivatives
in a valid hedging
relationship - - (74.3) - (74.3)
Reclassification of
hedging losses
included in income - - 18.5 - 18.5
Reclassification of
hedging gains
included in inventory - - (1.0) - (1.0)
Unrealized loss on
translation of
self-sustaining
foreign operations - - (59.0) - (59.0)
-------------------------------------------------------------------------
Total comprehensive
income - - (115.8) 114.7 (1.1)
-------------------------------------------------------------------------
Dividends declared on
common shares - - - (74.5) (74.5)
Common shares issued
under purchase plans 7.2 - - - -
Senior management stock
options exercised 1.6 - - - -
Stock option expense - 0.5 - - -
Other share-based
compensation 0.2 - - - -
-------------------------------------------------------------------------
Balance,
September 30, 2007 $1,064.2 $2.7 $(221.3) $488.4 $267.1
-------------------------------------------------------------------------
-------------------------------------------------------------------------
See accompanying notes to the unaudited consolidated financial
statements.
Notes to the Interim Unaudited Consolidated Financial Statements
September 30, 2008
1. Basis of Presentation
The disclosures in these unaudited interim consolidated financial
statements do not conform in all respects to the requirements of Canadian
Generally Accepted Accounting Principles for annual audited financial
statements and should be read in conjunction with Emera Inc.'s annual
consolidated financial statements as at and for the year ended December 31,
2007.
"Company", "Emera Inc." and "Emera" refer to Emera Inc. and all of its
consolidated subsidiaries and affiliates.
These consolidated financial statements follow the same accounting
policies and methods of computation as Emera Inc.'s annual audited
consolidated financial statements as at and for the year ended December 31,
2007, with the exception of the accounting policy changes disclosed in note 3.
2. Seasonal Nature of Operations
Interim results are not necessarily indicative of results for the full
year due primarily to seasonal factors. Sales and related production vary
significantly over the year, with Q1 and Q4, the strongest periods, reflecting
colder weather and fewer daylight hours in the winter season.
3. Changes in Accounting Policy
The Canadian Institute of Chartered Accountants ("CICA") has issued new
accounting standards 1535 Capital Disclosures, 3031 Inventories, 3862
Financial Instruments - Disclosures, and 3863 Financial Instruments -
Presentation which are applicable to Emera's 2008 fiscal year. The following
provides more information on each new accounting standard.
Capital Disclosures: This new standard requires disclosure of the
Company's objectives, policies, and processes for managing capital;
quantitative data about what the Company regards as capital; whether the
Company has complied with any externally imposed capital requirements; and, if
the Company has not complied, the consequences of such non-compliance. The new
accounting standard covers disclosure only and had no effect on the financial
results of the Company. Further information can be found in note 10.
Financial Instruments - Disclosures, and Financial Instruments -
Presentation: These new standards replace accounting standard 3861 Financial
Instruments - Disclosure and Presentation. Presentation requirements have not
changed. Enhanced disclosure is required to assist users of the financial
statements in evaluating the significance of financial instruments on the
Company's financial position and performance, including qualitative and
quantitative information about the Company's exposure to risks arising from
financial instruments. The new accounting standards cover disclosure only and
had no effect on the financial results of the Company. Further information can
be found in note 11.
Inventories
The new standard provides more guidance on the measurement and disclosure
requirements for inventories than the previous standard, 3030 Inventories.
Specifically, the new standard requires that inventories be measured at the
lower of cost and net realizable value, and provides more guidance on the
determination of cost and its subsequent recognition as an expense, including
any write-down to net realizable value. The Company previously measured
inventories at the lower of cost and market. The Company uses the weighted
average method to determine the cost of inventory.
The Company has applied the new standard retrospectively without
restatement, which resulted in a decrease to inventory and retained earnings
of $3.3 million as at January 1, 2008.
The change in inventory is due to the following:
Fuel inventory Materials inventory
Nine months ended Nine months ended
For the September 30 September 30
-------------------------------------------------------------------------
millions of dollars 2008 2007 2008 2007
-------------------------------------------------------------------------
Inventory, beginning of period $67.7 $81.2 $32.1 $32.4
Accounting policy change - - (3.3) -
Purchases 258.3 243.8 29.5 29.9
Write-down of inventory to net
realizable value - - (0.9) -
Inventories expensed (239.3) (253.3) (12.8) (13.0)
Inventories capitalized - - (17.3) (17.4)
Other - - 1.3 1.3
-------------------------------------------------------------------------
Inventory, end of period $86.7 $71.7 $28.6 $33.2
-------------------------------------------------------------------------
-------------------------------------------------------------------------
The Company has not pledged inventory as security for liabilities.
Future Accounting Policy Changes
Changeover to International Financial Reporting Standards ("IFRS"): In
April 2008, the CICA issued an IFRS Omnibus Exposure Draft which proposes that
publicly accountable enterprises be required to apply IFRS effective for
Emera's 2011 fiscal year with consistent comparative information required for
2010. The Company is currently assessing the effect of IFRS on its financial
statements and developing its changeover plan.
Goodwill and Intangible Assets: In February 2008, the CICA issued Section
3064 Goodwill and Intangible Assets ("3064") applicable to Emera's 2009 fiscal
year, replacing Section 3062 Goodwill and Other Intangible Assets. The
goodwill requirements have not changed. The requirements for intangible assets
now clarify that costs may only be deferred when they relate to an item that
meets the definition of an asset. An intangible asset must be identifiable; be
a resource over which the Company has control; probably generate future
economic benefits; and have a reliably measurable cost. The Company is
currently assessing the effect of 3064 on its financial statements but does
not expect a material change.
4. Segment Information
-------------------------------------------------------------------------
Nova Scotia Bangor
millions of dollars Power Hydro Other(x) Total
-------------------------------------------------------------------------
For the three months ended
September 30, 2008:
Revenues from external customers $254.2 $36.4 $5.2 $295.8
Net inter-segment revenues
(expenses) 22.4 (0.2) (22.2) -
Net earnings applicable to
common shares 2.3 6.5 (2.3) 6.5
For the nine months ended
September 30, 2008:
Revenues from external customers 842.2 105.0 47.4 994.6
Net inter-segment revenues
(expenses) 70.1 (0.6) (69.5) -
Net earnings applicable to
common shares 91.2 16.5 11.1 118.8
As at September 30, 2008
Total assets 3,242.0 665.5 898.4 4,805.9
-------------------------------------------------------------------------
For the three months ended
September 30, 2007:
Revenues from external customers $252.4 $36.2 $21.7 $310.3
Net inter-segment revenues
(expenses) 14.4 (0.5) (13.9) -
Net earnings applicable to
common shares 25.0 9.1 6.8 40.9
For the nine months ended
September 30, 2007:
Revenues from external customers 826.9 105.9 62.8 995.6
Net inter-segment revenues
(expenses) 71.7 (1.5) (70.2) -
Net earnings applicable to
common shares 75.0 20.8 18.9 114.7
As at September 30, 2007
Total assets 3,218.2 608.5 348.5 4,175.2
-------------------------------------------------------------------------
-------------------------------------------------------------------------
(x)Other includes corporate activities and adjustments to reconcile to
consolidated balances.
5. Employee Future Benefits
Emera maintains contributory defined-benefit and defined-contribution
pension plans, which cover substantially all of its employees, and plans that
provide non-pension benefits for its retirees. The Company's estimated total
benefit cost, related to these plans, for the three month period ended
September 30, 2008 is $8.7 million (2007 - $10.4 million), and for the nine
month period ended September 30, 2008 is $25.5 million (2007 - $31.4 million).
6. Financing Charges
Financing charges consist of the following:
Three months ended Nine months ended
For the September 30 September 30
-------------------------------------------------------------------------
millions of dollars 2008 2007 2008 2007
-------------------------------------------------------------------------
Interest - long-term debt $25.4 $24.7 $78.9 $76.6
- short-term debt 6.0 5.8 15.6 16.8
Preferred share dividends paid
by subsidiary 3.6 3.6 10.6 10.6
Amortization of defeasance cost 3.1 3.2 9.3 9.5
Amortization of debt financing
costs 0.4 0.5 1.2 1.4
Allowance for funds used during
construction (6.2) (3.5) (12.4) (9.1)
Foreign exchange (gains) losses (4.1) 1.5 (4.8) (0.5)
-------------------------------------------------------------------------
$28.2 $35.8 $98.4 $105.3
-------------------------------------------------------------------------
-------------------------------------------------------------------------
7. Income Taxes
2008
During 2008, NSPI accelerated deductibility of capitalized expenses
pertaining to the 2007 tax year. As a result, in 2008 NSPI recorded an income
tax recovery of $6.3 million of which $3.0 million was recorded in Q3.
2007
During 2007, NSPI prepared and filed with Canada Revenue Agency ("CRA")
amended tax returns for the years 2000 to 2004 inclusive. CRA reviewed and
approved the amended filings, which has resulted in accelerated deductibility
of certain capitalized expenses. As a result, in Q3 2007 NSPI recorded an
income tax recovery of $25.4 million, of which $14.6 million was recorded as a
reduction of deferred charges, specifically the regulatory asset related to
its pre-2003 income tax liability. The remaining $10.8 million was recorded as
a reduction of current income tax expense. NSPI also amended tax returns for
2005 and 2006 using the same methodology and will continue to use this
methodology when filing its future tax returns.
Accounting for the impact of rate regulation:
Absent NSPI's regulator approved taxes payable accounting policy, the
recoveries would have no effect on the total current and future income tax
expense and net earnings would have been $3.0 million lower (2007 - $10.8
million) for the three months ended September 30, 2008 and $6.3 million lower
(2007 - $10.8 million) for the nine months ended September 30, 2008.
8. Deferred Charges and Deferred Credits
Based on the terms and conditions of NSPI's defined-benefit pension plans
and non-pension benefit plans, the Company is required under the accounting
standards to disclose the accrued benefit assets and accrued benefit
liabilities separately rather than the net amount as previously disclosed. As
a result, the deferred charges and deferred credits as at December 31, 2007
have been increased by $55.2 million respectively. The change had no impact on
the measurement of cash flows, shareholders' equity, net earnings applicable
to common shares, and basic and diluted earnings per share.
9. Long-Term Debt
As of September 30, 2008, long-term debt includes $2.1 million (December
31, 2007 - $1.5 million) in capital lease obligations.
10. Capital Management
The Company includes shareholders' equity (excluding AOCI), short-term and
long-term debt, preferred shares issued by subsidiary, non-controlling
interest, securitized receivables, and cash and cash equivalents in the
definition of capital as follows:
As at September 30 December 31
millions of dollars 2008 2007
-------------------------------------------------------------------------
Shareholders' equity, excluding AOCI $1,618.0 $1,568.8
Debt 2,216.6 1,825.8
Preferred shares issued by subsidiary 260.0 260.0
Non-controlling interest 41.4 0.6
Securitized accounts receivable - 25.0
Cash and cash equivalents (28.5) (26.4)
-------------------------------------------------------------------------
$4,107.5 $3,653.8
-------------------------------------------------------------------------
-------------------------------------------------------------------------
The Company's objectives when managing capital are to ensure sufficient
liquidity and ongoing access to capital in order to allow the Company to
acquire, build and maintain its regulated electric utilities, low risk
unregulated generation and energy infrastructure businesses. The Company has a
strategy of managing its capital structure through its various wholly-owned
subsidiaries, while ensuring it is in compliance with its debt covenants. This
strategy is managed by the Company through the issuance from time to time of
shares, bonds, medium-term notes, preferred shares, or other indebtedness, and
sales of receivables through the Company's securitization program. The
securitization program was suspended in January 2008 due to increased pricing
and limitations of supply in the market.
NSPI is subject to regulation by the Utility and Review Board with an
allowed maximum common equity component of 40%. BHE is subject to regulation
by the Maine Public Utilities Commission with an allowed maximum common equity
component of 50% for rate-making purposes. The Federal Energy Regulatory
Commission does not specify an allowed common equity component for BHE. The
Company is in compliance with these requirements.
Emera Inc.'s syndicated bank credit agreement provides that the Company's
debt can not exceed 70% of the Company's capitalization. NSPI's trust
indentures, applicable to the senior unsecured debenture and senior unsecured
medium-term notes, provide that NSPI's funded debt cannot exceed 75% of total
capitalization as defined in the credit agreements. NSPI's syndicated bank
credit facility limits its debt to capitalization ratio to no greater than
0.65:1. BHE has short-term and long-term financing agreements that limit the
amount of debt to 65% of capitalization, limit priority debt to 15% of net
worth, limit earnings before interest, taxes, depreciation and amortization to
interest to 2:1, and requires net worth of at least $150 million. The Company
is in compliance with all of its financial debt covenants.
11. Financial Instruments
This note should be read in conjunction with Emera Inc.'s annual financial
statements' notes 1 and 22 as at and for the year ended December 31, 2007.
RISK MANAGEMENT
Market Risk
Market risks associated with derivatives, which includes the Company's
hedges and natural gas contracts, are related to movement in commodity prices
and foreign exchange rates. Market risk associated with short-term debt is
related to movement in interest rates. Market risk associated with the
long-term receivable and HFT natural gas contracts is related to movements in
commodity prices and foreign exchange rates.
As at September 30, 2008 the Company determined that market risk exposure
associated with its financial instruments would affect the Company's financial
results as follows:
After-tax After-tax
net earnings AOCI
increase increase
millions of dollars (decrease) (decrease)
-------------------------------------------------------------------------
$1 per one million British Thermal Unit increase
in the price of natural gas $2.2 $14.9
$5 per barrel increase in the price of heavy
fuel oil 0.6 4.0
$15 per metric tonne increase in the price
of coal - 19.1
$0.01 decrease in the strength of the Canadian
relative to the US dollar 0.3 10.0
100 basis point increase in the central bank
interest rates (0.2) -
$1 per megawatt hour increase in the price
of power 0.6 -
-------------------------------------------------------------------------
The above table illustrates the effect on the Company's financial results
due to a certain fixed price change on the entire portfolio of financial
instruments as at the end of the quarter. The results disclosed in the above
table cannot be extrapolated linearly to determine the effect on the Company's
financial results due to varying price changes.
Credit risk
As at September 30, 2008, the maximum exposure the Company has to credit
risk is $457.4 million, which includes accounts receivable, long-term
receivable, and the assets related to derivatives in a valid hedging
relationship, and held-for-trading derivatives, excluding NSPI's natural gas
contracts.
The Company transacts with counterparties as part of its risk management
strategy for managing commodity price, foreign exchange and interest rate
risk. Counterparties that exceed established credit limits can provide a cash
deposit or letter of credit to the Company for the value in excess of the
credit limit where contractually required. The Company also obtains cash
deposits from electric customers. The total cash deposits and letters of
credit on hand as at September 30, 2008 was $64.3 million, which mitigates the
Company's maximum credit risk exposure. The Company uses the cash as payment
for the amount receivable or returns the cash deposit to the counterparty
where the credit limit is no longer exceeded or where the customer is no
longer considered a high risk account.
The Company generally considers the credit quality of financial assets
that are neither past due nor impaired to be good. The Company monitors
collection performance to ensure payments are received on a timely basis.
The Company does not have any financial assets that would be considered to
be impaired.
As at September 30, 2008, the Company had $34.7 million in financial
assets considered to be past due, which have been outstanding for an average
of 76 days. The fair value of these financial assets is $31.0 million, the
difference of which is included in the allowance for doubtful accounts. These
assets primarily relate to accounts receivable from electric revenue.
Concentration risk
------------------
The Company's concentrations of risk as at September 30, 2008 is as
follows:
As at September 30, 2008 % of total
millions of dollars exposure
-------------------------------------------------------------------------
Accounts receivable
Regulated utilities
Residential $93.5 19%
Commercial 55.9 11%
Industrial 34.3 7%
Other 12.4 2%
-------------------------------------------------------------------------
196.1 39%
-------------------------------------------------------------------------
Trading group
Credit rating of A- or above 12.5 3%
Credit rating of BBB- to BBB+ 11.7 2%
Not rated 16.2 3%
Fully collateralized 16.9 3%
-------------------------------------------------------------------------
57.3 11%
-------------------------------------------------------------------------
Other accounts receivable 13.6 3%
-------------------------------------------------------------------------
267.0 53%
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Long-term receivable 51.3 10%
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Derivatives (in a valid hedging relationship and
held-for-trading; current and long-term portions)
Credit rating of A- or above $153.3 31%
Credit rating of BBB- to BBB+ 11.6 2%
Not rated 19.1 4%
-------------------------------------------------------------------------
184.0 37%
-------------------------------------------------------------------------
-------------------------------------------------------------------------
$502.3 100%
-------------------------------------------------------------------------
-------------------------------------------------------------------------
Liquidity risk
The Company has available the following credit facilities as at September
30, 2008 for the management of liquidity risk:
millions of dollars Available Used Unused
-------------------------------------------------------------------------
Bank operating, overdraft and commercial paper $1,163.6 $762.3 $401.3
-------------------------------------------------------------------------
-------------------------------------------------------------------------
AVAILABLE-FOR-SALE INVESTMENTS
Available-for-sale investments includes the Company's investment in
OpenHydro Group Limited ("OpenHydro"). The investment is recognized at its
cost of $15.4 million. The fair value of OpenHydro has not been recognized or
disclosed because its shares are not actively traded in an open market. The
Company does not intend to dispose of the investment in the near term. The
market for any disposition of OpenHydro shares would be with an existing
shareholder or a new private investor.
12. Common Shares
As at September 30, 2008 there were 112.1 million (December 31, 2007 -
111.5 million) issued and outstanding common shares, 4.5 million (December 31,
2007 - 4.8 million) common shares reserved and available for issuance under
the senior management stock option plan, and 0.9 million (December 31, 2007 -
1.0 million) common shares reserved and available for issuance under the
employee common share purchase plan.
During the nine months ended September 30, 2008, the Company issued 0.6
million (2007 - 0.4 million) common shares. Common shares were issued through
the employee common share purchase plan, the senior management stock option
plan, and the dividend reinvestment plan.
Diluted weighted average number of common shares outstanding includes the
conversion of preferred shares of NSPI, restricted share units, deferred share
units, and senior management share options.
13. Cash Flow Information
The change in non-cash operating working capital consists of the
following:
Three months ended Nine months ended
For the September 30 September 30
-------------------------------------------------------------------------
millions of dollars 2008 2007 2008 2007
-------------------------------------------------------------------------
Decrease in accounts receivable $26.3 $14.3 $41.6 $14.5
Decrease (increase) in inventory 15.6 3.5 (15.4) 8.2
Decrease (increase) in prepaid
expenses 8.9 9.1 (17.2) 4.3
Increase in long-term receivables (1.3) (6.4) (43.5) (25.5)
(Decrease) increase in posted
margin included in accounts
payable and accrued charges (74.1) (2.5) 14.4 3.5
Increase (decrease) in other
accounts payable and accrued
charges 21.4 (2.9) 18.7 (54.9)
(Decrease) increase in income
tax payable (12.6) (34.2) 4.2 (67.9)
-------------------------------------------------------------------------
$(15.8) $(19.1) $2.8 $(117.8)
-------------------------------------------------------------------------
-------------------------------------------------------------------------
14. Acquisitions
ICD Utilities Limited ("ICDU")
In September 2008, Emera purchased 50% of the shares of ICDU of the
Bahamas for $42.0 million USD ($44.9 million CAD). ICDU owns 50% of Grand
Bahama Power Company Limited ("GBPC") which is a vertically integrated utility
serving 19,000 customers on Grand Bahama Island.
GBPC has 137 megawatts of installed oil-fired generating capacity. The
Grand Bahama Port Authority Limited regulates the utility and has granted GBPC
a licensed, regulated and exclusive franchise to produce, transmit, and
distribute electricity on the island until 2054. There is a fuel pass through
mechanism and flexible tariff adjustment policies to ensure that costs are
recovered and a reasonable return is earned.
The acquisition has been accounted for under the purchase method of
accounting as Emera has determined it has control of ICDU, and accordingly,
the results of operations since the date of acquisition have been included in
the consolidated statements of earnings. ICDU is included in the segment
"Other" in Note 4 Segment Information. The following summarizes the
transaction:
Net assets acquired millions of dollars
-------------------------------------------------------------------------
Long-term investment $85.9
Non-controlling interest (41.0)
-------------------------------------------------------------------------
Cash paid $44.9
-------------------------------------------------------------------------
-------------------------------------------------------------------------
The purchase price allocation has not yet been finalized as the Company
has not completed the valuation of the long-term investment in GBPC.
OpenHydro Group Limited ("OpenHydro")
In February 2008 Emera acquired a 7.35% interest in OpenHydro, an Irish
renewable tidal energy company for (euro)10.2 million ($15.4 million CAD).
OpenHydro designs and manufactures marine turbines for harnessing energy from
tidal currents in the world's oceans.
The acquisition has been accounted for as an available-for-sale investment
as Emera has determined it does not have significant influence over the
investment, and accordingly, the investment was initially recorded at cost.
Any dividends received or receivable since acquisition will be recognized as
dividend income. OpenHydro is included in the segment "Other" in Note 4
Segment Information.
15. Commitments
During the nine months ended September 30, 2008, NSPI made commitments to
purchase 711 GWh of electricity from independent power producers beginning in
Q4 2009 with varying contract lengths ranging from 20 to 25 years.
16. Comparative Information
Certain of the comparative figures have been reclassified to conform to
the consolidated financial statement presentation adopted for 2008.